EOG RESOURCES INC - Quarter Report: 2021 March (Form 10-Q)
UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
| FORM | 10-Q | ||||
(Mark One)
☒ QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
For the quarterly period ended March 31, 2021
or
☐ TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
Commission File Number: 1-9743
EOG RESOURCES, INC.
(Exact name of registrant as specified in its charter)
| Delaware | 47-0684736 | |||||||
| (State or other jurisdiction of incorporation or organization) | (I.R.S. Employer Identification No.) | |||||||
1111 Bagby, Sky Lobby 2, Houston, Texas 77002
(Address of principal executive offices) (Zip Code)
713-651-7000
(Registrant's telephone number, including area code)
Securities registered pursuant to Section 12(b) of the Act:
| Title of each class | Trading symbol(s) | Name of each exchange on which registered | ||||||
| Common Stock, par value $0.01 per share | EOG | New York Stock Exchange | ||||||
Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. Yes ☒ No ☐
Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit such files). Yes ☒ No ☐
Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company, or an emerging growth company. See the definitions of "large accelerated filer," "accelerated filer," "smaller reporting company," and "emerging growth company" in Rule 12b-2 of the Exchange Act.
Large accelerated filer ☒ Accelerated filer ☐ Non-accelerated filer ☐
Smaller reporting company ☐ Emerging growth company ☐
If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ☐
Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).
Yes ☐ No ☒
Indicate the number of shares outstanding of each of the registrant's classes of common stock, as of the latest practicable date.
| Title of each class | Number of shares | ||||||||||
| Common Stock, par value $0.01 per share | 583,605,122 | (as of April 29, 2021) | |||||||||
EOG RESOURCES, INC.
TABLE OF CONTENTS
| PART I. | FINANCIAL INFORMATION | Page No. | |||||||||
| ITEM 1. | Financial Statements (Unaudited) | ||||||||||
| ITEM 2. | |||||||||||
| ITEM 3. | |||||||||||
| ITEM 4. | |||||||||||
| PART II. | OTHER INFORMATION | ||||||||||
| ITEM 1. | |||||||||||
| ITEM 2. | |||||||||||
| ITEM 4. | |||||||||||
| ITEM 6. | |||||||||||
-2-
PART I. FINANCIAL INFORMATION
ITEM 1. FINANCIAL STATEMENTS
EOG RESOURCES, INC.
CONDENSED CONSOLIDATED STATEMENTS OF INCOME AND COMPREHENSIVE INCOME
(In Millions, Except Per Share Data)
(Unaudited)
| Three Months Ended March 31, | |||||||||||
| 2021 | 2020 | ||||||||||
| Operating Revenues and Other | |||||||||||
| Crude Oil and Condensate | $ | 2,251 | $ | 2,065 | |||||||
| Natural Gas Liquids | 314 | 161 | |||||||||
| Natural Gas | 625 | 210 | |||||||||
Gains (Losses) on Mark-to-Market Commodity Derivative Contracts | (367) | 1,206 | |||||||||
Gathering, Processing and Marketing | 848 | 1,039 | |||||||||
| Gains (Losses) on Asset Dispositions, Net | (6) | 16 | |||||||||
| Other, Net | 29 | 21 | |||||||||
| Total | 3,694 | 4,718 | |||||||||
| Operating Expenses | |||||||||||
| Lease and Well | 270 | 330 | |||||||||
| Transportation Costs | 202 | 208 | |||||||||
| Gathering and Processing Costs | 139 | 128 | |||||||||
| Exploration Costs | 33 | 40 | |||||||||
| Dry Hole Costs | 11 | — | |||||||||
| Impairments | 44 | 1,573 | |||||||||
| Marketing Costs | 838 | 1,110 | |||||||||
| Depreciation, Depletion and Amortization | 900 | 1,000 | |||||||||
| General and Administrative | 110 | 114 | |||||||||
| Taxes Other Than Income | 215 | 157 | |||||||||
| Total | 2,762 | 4,660 | |||||||||
| Operating Income | 932 | 58 | |||||||||
| Other Income (Expense), Net | (4) | 18 | |||||||||
| Income Before Interest Expense and Income Taxes | 928 | 76 | |||||||||
| Interest Expense, Net | 47 | 45 | |||||||||
| Income Before Income Taxes | 881 | 31 | |||||||||
| Income Tax Provision | 204 | 21 | |||||||||
| Net Income | $ | 677 | $ | 10 | |||||||
| Net Income Per Share | |||||||||||
| Basic | $ | 1.17 | $ | 0.02 | |||||||
| Diluted | $ | 1.16 | $ | 0.02 | |||||||
| Average Number of Common Shares | |||||||||||
| Basic | 580 | 578 | |||||||||
| Diluted | 583 | 580 | |||||||||
| Comprehensive Income | |||||||||||
| Net Income | $ | 677 | $ | 10 | |||||||
| Other Comprehensive Income (Loss) | |||||||||||
| Foreign Currency Translation Adjustments | (2) | 2 | |||||||||
| Other, Net of Tax | — | — | |||||||||
| Other Comprehensive Income (Loss) | (2) | 2 | |||||||||
| Comprehensive Income | $ | 675 | $ | 12 | |||||||
The accompanying notes are an integral part of these condensed consolidated financial statements.
-3-
EOG RESOURCES, INC.
CONDENSED CONSOLIDATED BALANCE SHEETS
(In Millions, Except Share Data)
(Unaudited)
| March 31, 2021 | December 31, 2020 | ||||||||||
| ASSETS | |||||||||||
| 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 | |||||||
| LIABILITIES AND STOCKHOLDERS' EQUITY | |||||||||||
| 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 (Note 8) | |||||||||||
| 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 | |||||||
The accompanying notes are an integral part of these condensed consolidated financial statements.
-4-
EOG RESOURCES, INC.
CONDENSED CONSOLIDATED STATEMENTS OF STOCKHOLDERS' EQUITY
(In Millions, Except Per Share Data)
(Unaudited)
| Common Stock | Additional Paid In Capital | Accumulated Other Comprehensive Income (Loss) | Retained Earnings | Common Stock Held In Treasury | Total Stockholders' Equity | ||||||||||||||||||||||||||||||
| Balance at December 31, 2020 | $ | 206 | $ | 5,945 | $ | (12) | $ | 14,170 | $ | (7) | $ | 20,302 | |||||||||||||||||||||||
| Net Income | — | — | — | 677 | — | 677 | |||||||||||||||||||||||||||||
Common Stock Dividends Declared, $0.4125 Per Share | — | — | — | (241) | — | (241) | |||||||||||||||||||||||||||||
| Other Comprehensive Loss | — | — | (2) | — | — | (2) | |||||||||||||||||||||||||||||
Change in Treasury Stock - Stock Compensation Plans, Net | — | — | — | — | (9) | (9) | |||||||||||||||||||||||||||||
Restricted Stock and Restricted Stock Units, Net | — | (1) | — | — | 1 | — | |||||||||||||||||||||||||||||
| Stock-Based Compensation Expenses | — | 35 | — | — | — | 35 | |||||||||||||||||||||||||||||
| Treasury Stock Issued as Compensation | — | — | — | — | — | — | |||||||||||||||||||||||||||||
| Balance at March 31, 2021 | $ | 206 | $ | 5,979 | $ | (14) | $ | 14,606 | $ | (15) | $ | 20,762 | |||||||||||||||||||||||
| Common Stock | Additional Paid In Capital | Accumulated Other Comprehensive Income (Loss) | Retained Earnings | Common Stock Held In Treasury | Total Stockholders' Equity | ||||||||||||||||||||||||||||||
| Balance at December 31, 2019 | $ | 206 | $ | 5,817 | $ | (5) | $ | 15,649 | $ | (27) | $ | 21,640 | |||||||||||||||||||||||
| Net Income | — | — | — | 10 | — | 10 | |||||||||||||||||||||||||||||
Common Stock Dividends Declared, $0.375 Per Share | — | — | — | (219) | — | (219) | |||||||||||||||||||||||||||||
| Other Comprehensive Income | — | — | 2 | — | — | 2 | |||||||||||||||||||||||||||||
Change in Treasury Stock - Stock Compensation Plans, Net | — | — | — | — | (4) | (4) | |||||||||||||||||||||||||||||
Restricted Stock and Restricted Stock Units, Net | — | (4) | — | — | 4 | — | |||||||||||||||||||||||||||||
| Stock-Based Compensation Expenses | — | 40 | — | — | — | 40 | |||||||||||||||||||||||||||||
| Treasury Stock Issued as Compensation | — | — | — | — | 2 | 2 | |||||||||||||||||||||||||||||
| Balance at March 31, 2020 | $ | 206 | $ | 5,853 | $ | (3) | $ | 15,440 | $ | (25) | $ | 21,471 | |||||||||||||||||||||||
The accompanying notes are an integral part of these condensed consolidated financial statements.
-5-
EOG RESOURCES, INC.
CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
(In Millions)
(Unaudited)
| Three Months Ended March 31, | |||||||||||
| 2021 | 2020 | ||||||||||
| Cash Flows from Operating Activities | |||||||||||
| Reconciliation of Net Income to Net Cash Provided by Operating Activities: | |||||||||||
| Net Income | $ | 677 | $ | 10 | |||||||
| Items Not Requiring (Providing) Cash | |||||||||||
| Depreciation, Depletion and Amortization | 900 | 1,000 | |||||||||
| Impairments | 44 | 1,573 | |||||||||
| Stock-Based Compensation Expenses | 35 | 40 | |||||||||
| Deferred Income Taxes | (36) | 45 | |||||||||
| (Gains) Losses on Asset Dispositions, Net | 6 | (16) | |||||||||
| Other, Net | 7 | (9) | |||||||||
| Dry Hole Costs | 11 | — | |||||||||
| Mark-to-Market Commodity Derivative Contracts | |||||||||||
| Total (Gains) Losses | 367 | (1,206) | |||||||||
| Net Cash Received from (Payments for) Settlements of Commodity Derivative Contracts | (30) | 84 | |||||||||
| Other, Net | 1 | — | |||||||||
| Changes in Components of Working Capital and Other Assets and Liabilities | |||||||||||
| Accounts Receivable | (308) | 722 | |||||||||
| Inventories | 64 | 103 | |||||||||
| Accounts Payable | 172 | 434 | |||||||||
| Accrued Taxes Payable | 243 | (55) | |||||||||
| Other Assets | (103) | 58 | |||||||||
| Other Liabilities | (89) | (66) | |||||||||
| Changes in Components of Working Capital Associated with Investing Activities | (91) | (132) | |||||||||
| Net Cash Provided by Operating Activities | 1,870 | 2,585 | |||||||||
| Investing Cash Flows | |||||||||||
| Additions to Oil and Gas Properties | (875) | (1,566) | |||||||||
| Additions to Other Property, Plant and Equipment | (42) | (123) | |||||||||
| Proceeds from Sales of Assets | 5 | 26 | |||||||||
| Changes in Components of Working Capital Associated with Investing Activities | 91 | 132 | |||||||||
| Net Cash Used in Investing Activities | (821) | (1,531) | |||||||||
| Financing Cash Flows | |||||||||||
| Long-Term Debt Repayments | (750) | — | |||||||||
| Dividends Paid | (219) | (167) | |||||||||
| Treasury Stock Purchased | (10) | (5) | |||||||||
| Repayment of Finance Lease Liabilities | (9) | (3) | |||||||||
| Net Cash Used in Financing Activities | (988) | (175) | |||||||||
| Effect of Exchange Rate Changes on Cash | (2) | — | |||||||||
| Increase in Cash and Cash Equivalents | 59 | 879 | |||||||||
| Cash and Cash Equivalents at Beginning of Period | 3,329 | 2,028 | |||||||||
| Cash and Cash Equivalents at End of Period | $ | 3,388 | $ | 2,907 | |||||||
The accompanying notes are an integral part of these condensed consolidated financial statements.
-6-
EOG RESOURCES, INC.
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
(Unaudited)
1. Summary of Significant Accounting Policies
General. The condensed consolidated financial statements of EOG Resources, Inc., together with its subsidiaries (collectively, EOG), included herein have been prepared by management without audit pursuant to the rules and regulations of the United States Securities and Exchange Commission (SEC). Accordingly, they reflect all normal recurring adjustments which are, in the opinion of management, necessary for a fair presentation of the financial results for the interim periods presented. Certain information and notes normally included in financial statements prepared in accordance with accounting principles generally accepted in the United States of America (U.S. GAAP) have been condensed or omitted pursuant to such rules and regulations. However, management believes that the disclosures included either on the face of the financial statements or in these notes are sufficient to make the interim information presented not misleading. These condensed consolidated financial statements should be read in conjunction with the consolidated financial statements and the notes thereto included in EOG's Annual Report on Form 10-K for the year ended December 31, 2020, filed on February 25, 2021 (EOG's 2020 Annual Report).
The preparation of financial statements in conformity with U.S. GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates. The operating results for the three months ended March 31, 2021, are not necessarily indicative of the results to be expected for the full year.
Effective January 1, 2021, EOG adopted the provisions of Accounting Standards Update (ASU) 2019-12, "Income Taxes (Topic 740) Simplifying the Accounting for Income Taxes" (ASU 2019-12). ASU 2019-12 amends certain aspects of accounting for income taxes, including the removal of specific exceptions within existing U.S. GAAP related to the incremental approach for intraperiod tax allocation and updates to the general methodology for calculating income taxes in interim periods, among other changes. ASU 2019-12 also requires an entity to reflect the effect of an enacted change in tax laws or rates in the annual effective tax rate computation in the interim period that includes the enactment date, among other requirements. The effects of ASU 2019-12 applicable to EOG were all required on a prospective basis. There was no impact upon adoption of ASU 2019-12 to its consolidated financial statements or related disclosures.
Recently Issued Accounting Standards. In March 2020, the Financial Accounting Standards Board (FASB) issued ASU 2020-04, "Reference Rate Reform (Topic 848)" (ASU 2020-04), which provides optional expedients and exceptions for accounting treatment of contracts which are affected by the anticipated discontinuation of the London InterBank Offered Rate (LIBOR) and other rates resulting from rate reform. Contract terms that are modified due to the replacement of a reference rate are not required to be remeasured or reassessed under relevant accounting standards. Early adoption is permitted. ASU 2020-04 covers certain contracts which reference these rates and that are entered into on or before December 31, 2022. EOG is evaluating the provisions of ASU 2020-04 and has not determined the full impact on its consolidated financial statements and related disclosures related to its $2.0 billion senior unsecured Revolving Credit Agreement.
-7-
EOG RESOURCES, INC.
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – (Continued)
(Unaudited)
2. Stock-Based Compensation
As more fully discussed in Note 7 to the Consolidated Financial Statements included in EOG's 2020 Annual Report, EOG maintains various stock-based compensation plans. Stock-based compensation expense is included on the Condensed Consolidated Statements of Income and Comprehensive Income based upon the job function of the employees receiving the grants as follows (in millions):
| Three Months Ended March 31, | |||||||||||
| 2021 | 2020 | ||||||||||
| Lease and Well | $ | 14 | $ | 15 | |||||||
| Gathering and Processing Costs | — | — | |||||||||
| Exploration Costs | 6 | 7 | |||||||||
| General and Administrative | 15 | 18 | |||||||||
| Total | $ | 35 | $ | 40 | |||||||
The Amended and Restated EOG Resources, Inc. 2008 Omnibus Equity Compensation Plan (2008 Plan) provided for grants of stock options, stock-settled stock appreciation rights (SARs), restricted stock and restricted stock units, performance units and other stock-based awards.
At March 31, 2021, approximately 2 million common shares remained available for grant under the 2008 Plan.
EOG's stockholders approved the EOG Resources, Inc. 2021 Omnibus Equity Compensation Plan (2021 Plan) at the 2021 Annual Meeting of Stockholders. Therefore, no further grants will be made from the 2008 Plan from and after the April 29, 2021 effective date of the 2021 Plan. The 2021 Plan provides for grants of stock options, SARs, restricted stock and restricted stock units and other stock-based awards, up to an aggregate maximum of 20 million shares of common stock, plus any shares that are subject to outstanding awards under the 2008 Plan as of April 29, 2021, that are subsequently canceled, forfeited, expire or are otherwise not issued or are settled in cash. Under the 2021 Plan, grants may be made to employees and non-employee members of EOG's Board of Directors (Board). EOG's policy is to issue shares related to 2021 Plan grants from previously authorized unissued shares or treasury shares to the extent treasury shares are available.
Stock Options and Stock-Settled Stock Appreciation Rights and Employee Stock Purchase Plan. The fair value of stock option grants and SAR grants is estimated using the Hull-White II binomial option pricing model. The fair value of Employee Stock Purchase Plan (ESPP) grants is estimated using the Black-Scholes-Merton model. Stock-based compensation expense related to stock option, SAR and ESPP grants totaled $10 million and $14 million during the three months ended March 31, 2021 and 2020, respectively.
Weighted average fair values and valuation assumptions used to value stock option, SAR and ESPP grants during the three-month periods ended March 31, 2021 and 2020 are as follows:
| Stock Options/SARs | ESPP | ||||||||||||||||||||||
| Three Months Ended March 31, | Three Months Ended March 31, | ||||||||||||||||||||||
| 2021 | 2020 | 2021 | 2020 | ||||||||||||||||||||
| Weighted Average Fair Value of Grants | $ | 17.03 | $ | 19.67 | $ | 14.69 | $ | 20.80 | |||||||||||||||
| Expected Volatility | 47.18 | % | 33.43 | % | 54.99 | % | 35.24 | % | |||||||||||||||
| Risk-Free Interest Rate | 0.28 | % | 1.43 | % | 0.09 | % | 1.56 | % | |||||||||||||||
| Dividend Yield | 3.25 | % | 1.60 | % | 3.41 | % | 1.56 | % | |||||||||||||||
| Expected Life | 5.2 years | 5.0 years | 0.5 years | 0.5 years | |||||||||||||||||||
Expected volatility is based on an equal weighting of historical volatility and implied volatility from traded options in EOG's common stock. The risk-free interest rate is based upon United States Treasury yields in effect at the time of grant. The expected life is based upon historical experience and contractual terms of stock option, SAR and ESPP grants.
-8-
EOG RESOURCES, INC.
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – (Continued)
(Unaudited)
The following table sets forth stock option and SAR transactions for the three-month periods ended March 31, 2021 and 2020 (stock options and SARs in thousands):
| Three Months Ended March 31, 2021 | Three Months Ended March 31, 2020 | ||||||||||||||||||||||
| Number of Stock Options/SARs | Weighted Average Grant Price | Number of Stock Options/SARs | Weighted Average Grant Price | ||||||||||||||||||||
| Outstanding at January 1 | 10,186 | $ | 84.08 | 9,395 | $ | 94.53 | |||||||||||||||||
| Granted | 7 | 53.98 | 9 | 75.44 | |||||||||||||||||||
Exercised (1) | (26) | 63.25 | (23) | 69.59 | |||||||||||||||||||
| Forfeited | (103) | 89.21 | (47) | 96.81 | |||||||||||||||||||
Outstanding at March 31 (2) | 10,064 | $ | 84.06 | 9,334 | $ | 94.56 | |||||||||||||||||
Vested or Expected to Vest (3) | 9,749 | $ | 84.74 | 8,998 | $ | 94.55 | |||||||||||||||||
Exercisable at March 31 (4) | 6,288 | $ | 96.47 | 5,249 | $ | 94.33 | |||||||||||||||||
(1)The total intrinsic value of stock options/SARs exercised during the three months ended March 31, 2021 and 2020 was $0.2 million and $0.4 million, respectively. The intrinsic value is based upon the difference between the market price of EOG's common stock on the date of exercise and the grant price of the stock options/SARs.
(2)The total intrinsic value of stock options/SARs outstanding at March 31, 2021 and 2020 was $71 million and zero, respectively. At March 31, 2021 and 2020, the weighted average remaining contractual life was 4.0 years.
(3)The total intrinsic value of stock options/SARs vested or expected to vest at March 31, 2021 and 2020 was $66 million and zero, respectively. At March 31, 2021 and 2020, the weighted average remaining contractual life was 4.0 years.
(4)The total intrinsic value of stock options/SARs exercisable at March 31, 2021 and 2020 was $3 million and zero, respectively. At March 31, 2021 and 2020, the weighted average remaining contractual life was 3.0 years and 2.8 years, respectively.
At March 31, 2021, unrecognized compensation expense related to non-vested stock option, SAR and ESPP grants totaled $47 million. Such unrecognized expense will be amortized on a straight-line basis over a weighted average period of 1.9 years.
Restricted Stock and Restricted Stock Units. Employees may be granted restricted (non-vested) stock and/or restricted stock units without cost to them. Stock-based compensation expense related to restricted stock and restricted stock units totaled $24 million and $25 million for the three months ended March 31, 2021 and 2020, respectively.
-9-
EOG RESOURCES, INC.
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – (Continued)
(Unaudited)
The following table sets forth restricted stock and restricted stock unit transactions for the three-month periods ended March 31, 2021 and 2020 (shares and units in thousands):
| Three Months Ended March 31, 2021 | Three Months Ended March 31, 2020 | ||||||||||||||||||||||
| Number of Shares and Units | Weighted Average Grant Date Fair Value | Number of Shares and Units | Weighted Average Grant Date Fair Value | ||||||||||||||||||||
| Outstanding at January 1 | 4,742 | $ | 74.97 | 4,546 | $ | 90.16 | |||||||||||||||||
| Granted | 12 | 60.27 | 26 | 63.48 | |||||||||||||||||||
Released (1) | (430) | 90.27 | (259) | 88.19 | |||||||||||||||||||
| Forfeited | (25) | 71.16 | (11) | 89.86 | |||||||||||||||||||
Outstanding at March 31 (2) | 4,299 | $ | 73.42 | 4,302 | $ | 90.12 | |||||||||||||||||
(1)The total intrinsic value of restricted stock and restricted stock units released during the three months ended March 31, 2021 and 2020 was $31 million and $11 million, respectively. The intrinsic value is based upon the closing price of EOG's common stock on the date the restricted stock and restricted stock units are released.
(2)The total intrinsic value of restricted stock and restricted stock units outstanding at March 31, 2021 and 2020 was $312 million and $155 million, respectively.
At March 31, 2021, unrecognized compensation expense related to restricted stock and restricted stock units totaled $153 million. Such unrecognized expense will be amortized on a straight-line basis over a weighted average period of 1.5 years.
Performance Units. EOG grants performance units annually to its executive officers without cost to them. As more fully discussed in the grant agreements, the performance metric applicable to the performance units is EOG's total shareholder return over a three-year performance period relative to the total shareholder return of a designated group of peer companies (Performance Period). Upon the application of the performance multiple at the completion of the Performance Period, a minimum of 0% and a maximum of 200% of the performance units granted could be outstanding. The fair value of the performance units is estimated using a Monte Carlo simulation. Stock-based compensation expense related to the performance unit grants totaled $1 million for the each of the three months ended March 31, 2021 and 2020.
-10-
EOG RESOURCES, INC.
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – (Continued)
(Unaudited)
The following table sets forth the performance unit transactions for the three-month periods ended March 31, 2021 and 2020 (units in thousands):
| Three Months Ended March 31, 2021 | Three Months Ended March 31, 2020 | ||||||||||||||||||||||
| Number of Units | Weighted Average Price per Grant Date | Number of Units | Weighted Average Price per Grant Date | ||||||||||||||||||||
| Outstanding at January 1 | 613 | $ | 79.10 | 598 | $ | 92.19 | |||||||||||||||||
| Granted | 8 | 49.86 | — | — | |||||||||||||||||||
Granted for Performance Multiple (1) | 19 | 96.29 | 66 | 100.95 | |||||||||||||||||||
Released (2) | (98) | 96.29 | (121) | 104.69 | |||||||||||||||||||
| Forfeited | — | — | — | — | |||||||||||||||||||
Outstanding at March 31 (3) | 542 | (4) | $ | 76.18 | 543 | $ | 90.48 | ||||||||||||||||
(1)Upon completion of the Performance Period for the performance units granted in 2017 and 2016, a performance multiple of 125% and 150%, respectively, was applied to each of the grants resulting in additional grants of performance units in February 2021 and February 2020, respectively.
(2)The total intrinsic value of performance units released during the three months ended March 31, 2021 and 2020 was $6 million and $9 million, respectively. The intrinsic value is based upon the closing price of EOG's common stock on the date the performance units are released.
(3)The total intrinsic value of performance units outstanding at March 31, 2021 and 2020 was approximately $39 million and $20 million, respectively.
(4)Upon the application of the relevant performance multiple at the completion of each of the remaining Performance Periods, a minimum of 76,785 and a maximum of 1,007,705 performance units could be outstanding.
At March 31, 2021, unrecognized compensation expense related to performance units totaled $7 million. Such unrecognized expense will be amortized on a straight-line basis over a weighted average period of 1.9 years.
-11-
EOG RESOURCES, INC.
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – (Continued)
(Unaudited)
3. Net Income Per Share
The following table sets forth the computation of Net Income Per Share for the three-month periods ended March 31, 2021 and 2020 (in millions, except per share data):
| Three Months Ended March 31, | |||||||||||
| 2021 | 2020 | ||||||||||
| Numerator for Basic and Diluted Earnings Per Share - | |||||||||||
| Net Income | $ | 677 | $ | 10 | |||||||
| Denominator for Basic Earnings Per Share - | |||||||||||
| Weighted Average Shares | 580 | 578 | |||||||||
| Potential Dilutive Common Shares - | |||||||||||
| Stock Options/SARs/ESPP | 1 | — | |||||||||
| Restricted Stock/Units and Performance Units | 2 | 2 | |||||||||
| Denominator for Diluted Earnings Per Share - | |||||||||||
| Adjusted Diluted Weighted Average Shares | 583 | 580 | |||||||||
| Net Income Per Share | |||||||||||
| Basic | $ | 1.17 | $ | 0.02 | |||||||
| Diluted | $ | 1.16 | $ | 0.02 | |||||||
The diluted earnings per share calculation excludes stock option, SAR, and ESPP grants that were anti-dilutive. Shares underlying the excluded stock option, SAR and ESPP grants were 8 million and 9 million shares for the three months ended March 31, 2021 and 2020, respectively.
4. Supplemental Cash Flow Information
Net cash paid for interest and income taxes was as follows for the three-month periods ended March 31, 2021 and 2020 (in millions):
| Three Months Ended March 31, | |||||||||||
| 2021 | 2020 | ||||||||||
Interest (1) | $ | 49 | $ | 47 | |||||||
| Income Taxes, Net of Refunds Received | $ | 20 | $ | 15 | |||||||
(1)Net of capitalized interest of $8 million and $9 million for the three months ended March 31, 2021 and 2020, respectively.
EOG's accrued capital expenditures at March 31, 2021 and 2020 were $436 million and $642 million, respectively.
Non-cash investing activities for the three months ended March 31, 2021 and 2020, included additions of $25 million and $29 million, respectively, to EOG's oil and gas properties as a result of property exchanges. Non-cash investing activities for the three months ended March 31, 2021 and 2020, also included additions of $74 million and $49 million, respectively, to EOG's other property, plant and equipment made in connection with finance lease transactions for storage facilities.
-12-
EOG RESOURCES, INC.
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – (Continued)
(Unaudited)
5. Segment Information
Selected financial information by reportable segment is presented below for the three-month periods ended March 31, 2021 and 2020 (in millions):
| Three Months Ended March 31, | |||||||||||
| 2021 | 2020 | ||||||||||
| Operating Revenues and Other | |||||||||||
| United States | $ | 3,606 | $ | 4,661 | |||||||
| Trinidad | 76 | 42 | |||||||||
Other International (1) | 12 | 15 | |||||||||
| Total | 3,694 | 4,718 | |||||||||
| Operating Income (Loss) | |||||||||||
United States (2) | 890 | 105 | |||||||||
| Trinidad | 43 | 13 | |||||||||
Other International (1) (3) | (1) | (60) | |||||||||
| Total | 932 | 58 | |||||||||
| Reconciling Items | |||||||||||
| Other Income (Expense), Net | (4) | 18 | |||||||||
| Interest Expense, Net | (47) | (45) | |||||||||
| Income Before Income Taxes | $ | 881 | $ | 31 | |||||||
(1) Other International primarily consists of EOG's China and Canada operations. EOG began an exploration program in Oman in the third quarter of 2020.
(2) EOG recorded pretax impairment charges of $1,456 million for the three months ended March 31, 2020, for proved oil and gas properties, leasehold costs and other assets due to the decline in commodity prices.
(3) EOG recorded pretax impairment charges of $60 million for the three months ended March 31, 2020, for firm commitment contracts related to its decision to exit the Horn River Basin in British Columbia, Canada.
Total assets by reportable segment are presented below at March 31, 2021 and December 31, 2020 (in millions):
| At March 31, 2021 | At December 31, 2020 | ||||||||||
| Total Assets | |||||||||||
| United States | $ | 35,395 | $ | 35,048 | |||||||
| Trinidad | 586 | 546 | |||||||||
Other International (1) | 190 | 211 | |||||||||
| Total | $ | 36,171 | $ | 35,805 | |||||||
(1) Other International primarily consists of EOG's China and Canada operations. EOG began an exploration program in Oman in the third quarter of 2020.
-13-
EOG RESOURCES, INC.
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – (Continued)
(Unaudited)
6. Asset Retirement Obligations
The following table presents the reconciliation of the beginning and ending aggregate carrying amounts of short-term and long-term legal obligations associated with the retirement of property, plant and equipment for the three-month periods ended March 31, 2021 and 2020 (in millions):
| Three Months Ended March 31, | |||||||||||
| 2021 | 2020 | ||||||||||
| Carrying Amount at January 1 | $ | 1,217 | $ | 1,111 | |||||||
| Liabilities Incurred | 12 | 15 | |||||||||
Liabilities Settled (1) | (5) | (24) | |||||||||
| Accretion | 11 | 11 | |||||||||
| Revisions | 2 | — | |||||||||
Carrying Amount at March 31 | $ | 1,237 | $ | 1,113 | |||||||
| Current Portion | $ | 49 | $ | 38 | |||||||
| Noncurrent Portion | $ | 1,188 | $ | 1,075 | |||||||
(1)Includes settlements related to asset sales.
The current and noncurrent portions of EOG's asset retirement obligations are included in Current Liabilities - Other and Other Liabilities, respectively, on the Condensed Consolidated Balance Sheets.
7. Exploratory Well Costs
EOG's net changes in capitalized exploratory well costs for the three-month period ended March 31, 2021, are presented below (in millions):
| Three Months Ended March 31, 2021 | |||||
| Balance at January 1 | $ | 29 | |||
| Additions Pending the Determination of Proved Reserves | 12 | ||||
| Reclassifications to Proved Properties | (3) | ||||
Costs Charged to Expense (1) | (5) | ||||
| Balance at March 31 | $ | 33 | |||
(1)Includes capitalized exploratory well costs charged to either dry hole costs or impairments.
| Three Months Ended March 31, 2021 | |||||
| Capitalized exploratory well costs that have been capitalized for a period of one year or less | $ | 18 | |||
Capitalized exploratory well costs that have been capitalized for a period greater than one year (1) | 15 | ||||
| Balance at March 31 | $ | 33 | |||
| Number of exploratory wells that have been capitalized for a period greater than one year | 1 | ||||
(1)Consists of costs related to a project in Trinidad at March 31, 2021.
-14-
EOG RESOURCES, INC.
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – (Continued)
(Unaudited)
8. Commitments and Contingencies
There are currently various suits and claims pending against EOG that have arisen in the ordinary course of EOG's business, including contract disputes, personal injury and property damage claims and title disputes. While the ultimate outcome and impact on EOG cannot be predicted, management believes that the resolution of these suits and claims will not, individually or in the aggregate, have a material adverse effect on EOG's consolidated financial position, results of operations or cash flow. EOG records reserves for contingencies when information available indicates that a loss is probable and the amount of the loss can be reasonably estimated.
9. Pension and Postretirement Benefits
Pension Plans. EOG has a defined contribution pension plan in place for most of its employees in the United States. EOG's contributions to the pension plan are based on various percentages of compensation and, in some instances, are based upon the amount of the employees' contributions. EOG's total costs recognized for the pension plan were $12 million and $9 million for the three months ended March 31, 2021 and 2020, respectively. In addition, EOG's Trinidadian subsidiary maintains a contributory defined benefit pension plan and a matched savings plan, both of which are available to most of its employees of the Trinidadian subsidiary, the costs of which are not material.
Postretirement Health Care. EOG has postretirement medical and dental benefits in place for eligible United States and Trinidad employees and their eligible dependents, the costs of which are not material.
10. Long-Term Debt and Common Stock
Long-Term Debt. EOG had no outstanding commercial paper borrowings at March 31, 2021 and December 31, 2020, and did not utilize any commercial paper borrowings during the three months ended March 31, 2021 and 2020.
EOG currently has a $2.0 billion senior unsecured Revolving Credit Agreement (Agreement) with domestic and foreign lenders (Banks). The Agreement has a scheduled maturity date of June 27, 2024, and includes an option for EOG to extend, on up to two occasions, the term for successive one-year periods subject to certain terms and conditions. The Agreement (i) commits the Banks to provide advances up to an aggregate principal amount of $2.0 billion at any one time outstanding, with an option for EOG to request increases in the aggregate commitments to an amount not to exceed $3.0 billion, subject to certain terms and conditions and (ii) includes a swingline subfacility and a letter of credit subfacility. Advances under the Agreement will accrue interest based, at EOG's option, on either LIBOR plus an applicable margin (Eurodollar rate) or the base rate (as defined in the Agreement) plus an applicable margin. The Agreement contains representations, warranties, covenants and events of default that EOG believes are customary for investment-grade, senior unsecured commercial bank credit agreements, including a financial covenant for the maintenance of a ratio of total debt-to-capitalization (as such terms are defined in the Agreement) of no greater than 65%. At March 31, 2021, EOG was in compliance with this financial covenant. At March 31, 2021 and December 31, 2020, there were no borrowings or letters of credit outstanding under the Agreement. The Eurodollar rate and base rate (inclusive of the applicable margin), had there been any amounts borrowed under the Agreement at March 31, 2021, would have been 1.01% and 3.25%, respectively.
On February 1, 2021, EOG repaid upon maturity the $750 million aggregate principal amount of its 4.100% Senior Notes due 2021.
Common Stock. On February 25, 2021, EOG's Board increased the quarterly cash dividend on the common stock from the previous $0.375 per share to $0.4125 per share, effective beginning with the dividend paid on April 30, 2021, to stockholders of record as of April 16, 2021. In addition, on May 6, 2021, EOG's Board declared a special cash dividend on the common stock of $1.00 per share. The special cash dividend, which is in addition to the quarterly cash dividend, is payable on July 30, 2021 to stockholders of record as of July 16, 2021.
-15-
EOG RESOURCES, INC.
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – (Continued)
(Unaudited)
11. Fair Value Measurements
Recurring Fair Value Measurements. As more fully discussed in Note 13 to the Consolidated Financial Statements included in EOG's 2020 Annual Report, certain of EOG's financial and nonfinancial assets and liabilities are reported at fair value on the Condensed Consolidated Balance Sheets. The following table provides fair value measurement information within the fair value hierarchy for certain of EOG's financial assets and liabilities carried at fair value on a recurring basis at March 31, 2021 and December 31, 2020 (in millions):
| Fair Value Measurements Using: | |||||||||||||||||||||||
| Quoted Prices in Active Markets (Level 1) | Significant Other Observable Inputs (Level 2) | Significant Unobservable Inputs (Level 3) | Total | ||||||||||||||||||||
| At March 31, 2021 | |||||||||||||||||||||||
| Financial Assets: | |||||||||||||||||||||||
| Natural Gas Swaps | $ | — | $ | 23 | $ | — | $ | 23 | |||||||||||||||
| Financial Liabilities: | |||||||||||||||||||||||
| Natural Gas Swaps | — | 5 | — | 5 | |||||||||||||||||||
| Crude Oil Swaps | — | 175 | — | 175 | |||||||||||||||||||
| Crude Oil Roll Differential Swaps | — | 20 | — | 20 | |||||||||||||||||||
| Natural Gas Liquids Swaps | — | 18 | — | 18 | |||||||||||||||||||
| At December 31, 2020 | |||||||||||||||||||||||
| Financial Assets: | |||||||||||||||||||||||
| Natural Gas Swaps | $ | — | $ | 66 | $ | — | $ | 66 | |||||||||||||||
| Financial Liabilities: | |||||||||||||||||||||||
| Crude Oil Roll Differential Swaps | — | 1 | — | 1 | |||||||||||||||||||
See Note 12 for the balance sheet amounts and classification of EOG's financial derivative instruments at March 31, 2021 and December 31, 2020.
The estimated fair value of commodity derivative contracts was based upon forward commodity price curves based on quoted market prices. Commodity derivative contracts were valued by utilizing an independent third-party derivative valuation provider who uses various types of valuation models, as applicable.
Non-Recurring Fair Value Measurements. The initial measurement of asset retirement obligations at fair value is calculated using discounted cash flow techniques and based on internal estimates of future retirement costs associated with property, plant and equipment. Significant Level 3 inputs used in the calculation of asset retirement obligations include plugging costs and reserve lives. A reconciliation of EOG's asset retirement obligations is presented in Note 6.
-16-
EOG RESOURCES, INC.
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – (Continued)
(Unaudited)
When circumstances indicate that proved oil and gas properties may be impaired, EOG compares expected undiscounted future cash flows at a depreciation, depletion and amortization group level to the unamortized capitalized cost of the asset. If the expected undiscounted future cash flows, based on EOG's estimate of (and assumptions regarding) significant Level 3 inputs, including future crude oil, NGLs and natural gas prices, operating costs, development expenditures, anticipated production from proved reserves and other relevant data, are lower than the unamortized capitalized cost, the capitalized cost is reduced to fair value. Fair value is generally calculated using the Income Approach described in the Fair Value Measurement Topic of the ASC. In certain instances, EOG utilizes accepted offers from third-party purchasers as the basis for determining fair value.
EOG utilized average prices per acre from comparable market transactions and estimated discounted cash flows as the basis for determining the fair value of unproved and proved properties, respectively, received in non-cash property exchanges. See Note 4.
Fair Value Disclosures. EOG's financial instruments, other than commodity derivative contracts, consist of cash and cash equivalents, accounts receivable, accounts payable and current and long-term debt. The carrying values of cash and cash equivalents, accounts receivable and accounts payable approximate fair value.
At March 31, 2021 and December 31, 2020, respectively, EOG had outstanding $4,890 million and $5,640 million aggregate principal amount of senior notes, which had estimated fair values at such dates of approximately $5,478 million and $6,505 million, respectively. The estimated fair value of debt was based upon quoted market prices and, where such prices were not available, other observable (Level 2) inputs regarding interest rates available to EOG at the end of each respective period.
12. Risk Management Activities
Commodity Price Risk. As more fully discussed in Note 12 to the Consolidated Financial Statements included in EOG's 2020 Annual Report, EOG engages in price risk management activities from time to time. These activities are intended to manage EOG's exposure to fluctuations in commodity prices for crude oil, NGLs and natural gas. EOG utilizes financial commodity derivative instruments, primarily price swap, option, swaption, collar and basis swap contracts, as a means to manage this price risk. EOG has not designated any of its financial commodity derivative contracts as accounting hedges and, accordingly, accounts for financial commodity derivative contracts using the mark-to-market accounting method.
Commodity Derivative Contracts. Presented below is a comprehensive summary of EOG's financial commodity derivative contracts as of March 31, 2021. Crude oil and NGL volumes are presented in thousand barrels per day (MBbld) and prices are presented in dollars per barrel ($/Bbl). Natural gas volumes are presented in million British Thermal Units per day (MMBtud) and prices are presented in dollars per million British Thermal Units ($/MMBtu).
| Crude Oil Financial Price Swap Contracts | ||||||||||||||||||||
| Contracts Sold | ||||||||||||||||||||
| Period | Settlement Index | Volume (MBbld) | Weighted Average Price ($/Bbl) | |||||||||||||||||
| January 2021 (closed) | New York Mercantile Exchange (NYMEX) West Texas Intermediate (WTI) | 151 | $ | 50.06 | ||||||||||||||||
| February - March 2021 (closed) | NYMEX WTI | 201 | 51.29 | |||||||||||||||||
| April - June 2021 | NYMEX WTI | 150 | 51.68 | |||||||||||||||||
| July - September 2021 | NYMEX WTI | 150 | 52.71 | |||||||||||||||||
-17-
EOG RESOURCES, INC.
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – (Continued)
(Unaudited)
| Crude Oil Basis Swap Contracts | ||||||||||||||||||||
| Contracts Sold | ||||||||||||||||||||
| Period | Settlement Index | Volume (MBbld) | Weighted Average Price Differential ($/Bbl) | |||||||||||||||||
| February 2021 (closed) | NYMEX WTI Roll Differential (1) | 30 | $ | 0.11 | ||||||||||||||||
| March - April 2021 (closed) | NYMEX WTI Roll Differential (1) | 125 | 0.17 | |||||||||||||||||
| May - December 2021 | NYMEX WTI Roll Differential (1) | 125 | 0.17 | |||||||||||||||||
| January - 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.
| NGL Financial Price Swap Contracts | ||||||||||||||||||||
| Contracts Sold | ||||||||||||||||||||
| Period | Settlement Index | Volume (MBbld) | Weighted Average Price ($/Bbl) | |||||||||||||||||
| January - March 2021 (closed) | Mont Belvieu Propane (non-Tet) | 15 | $ | 29.44 | ||||||||||||||||
| April - December 2021 | Mont Belvieu Propane (non-Tet) | 15 | 29.44 | |||||||||||||||||
| Natural Gas Financial Price Swap Contracts | ||||||||||||||||||||||||||||||||
| Contracts Sold | Contracts Purchased | |||||||||||||||||||||||||||||||
| Period | Settlement Index | Volume (MMBtud in thousands) | Weighted AveragePrice ($/MMBtu) | Volume (MMBtud in thousands) | Weighted Average Price ($/MMBtu) | |||||||||||||||||||||||||||
| January - March 2021 (closed) | NYMEX Henry Hub | 500 | $ | 2.99 | 500 | $ | 2.43 | |||||||||||||||||||||||||
| April - September 2021 | NYMEX Henry Hub | 500 | 2.99 | 570 | 2.81 | |||||||||||||||||||||||||||
| October - December 2021 | NYMEX Henry Hub | 500 | 2.99 | 500 | 2.83 | |||||||||||||||||||||||||||
January - December 2022 (closed) (1) | NYMEX Henry Hub | 20 | 2.75 | — | — | |||||||||||||||||||||||||||
| April 2021 (closed) | Japan Korea Marker (JKM) | 70 | 6.65 | — | — | |||||||||||||||||||||||||||
| May - September 2021 | JKM | 70 | 6.65 | — | — | |||||||||||||||||||||||||||
_________________
(1) In January 2021, EOG executed the early termination provision granting EOG the right to terminate all of its open 2022 natural gas price swap contracts. EOG received net cash of $0.6 million for the settlement of these contracts.
-18-
EOG RESOURCES, INC.
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – (Concluded)
(Unaudited)
Commodity Derivatives Location on Balance Sheet. The following table sets forth the amounts and classification of EOG's outstanding financial derivative instruments at March 31, 2021 and December 31, 2020. Certain amounts may be presented on a net basis on the Condensed Consolidated Financial Statements when such amounts are with the same counterparty and subject to a master netting arrangement (in millions):
| Fair Value at | ||||||||||||||||||||
| Description | Location on Balance Sheet | March 31, 2021 | December 31, 2020 | |||||||||||||||||
| Asset Derivatives | ||||||||||||||||||||
Crude oil, NGLs and natural gas derivative contracts - | ||||||||||||||||||||
| Current portion | Assets from Price Risk Management Activities | $ | — | $ | 65 | |||||||||||||||
| Noncurrent Portion | Other Assets | — | 1 | |||||||||||||||||
| Liability Derivatives | ||||||||||||||||||||
Crude oil, NGLs and natural gas derivative contracts - | ||||||||||||||||||||
| Current portion | Liabilities from Price Risk Management Activities (1) | $ | 188 | $ | — | |||||||||||||||
| Noncurrent portion | Other Liabilities | 7 | 1 | |||||||||||||||||
(1) The current portion of Liabilities from Price Risk Management Activities consists of gross liabilities of $211 million, partially offset by gross assets of $23 million, at March 31, 2021.
Credit Risk. Notional contract amounts are used to express the magnitude of a financial derivative. The amounts potentially subject to credit risk, in the event of nonperformance by the counterparties, are equal to the fair value of such contracts (see Note 11). EOG evaluates its exposures to significant counterparties on an ongoing basis, including those arising from physical and financial transactions. In some instances, EOG renegotiates payment terms and/or requires collateral, parent guarantees or letters of credit to minimize credit risk.
All of EOG's derivative instruments are covered by International Swap Dealers Association Master Agreements (ISDAs) with counterparties. The ISDAs may contain provisions that require EOG, if it is the party in a net liability position, to post collateral when the amount of the net liability exceeds the threshold level specified for EOG's then-current credit ratings. In addition, the ISDAs may also provide that as a result of certain circumstances, including certain events that cause EOG's credit ratings to become materially weaker than its then-current ratings, the counterparty may require all outstanding derivatives under the ISDAs to be settled immediately. See Note 11 for the aggregate fair value of all derivative instruments that were in a net liability position at March 31, 2021 and a net asset position at December 31, 2020. EOG had $19 million of collateral posted and no collateral held at March 31, 2021, and had no collateral posted or held at December 31, 2020.
13. Acquisitions and Divestitures
During the three months ended March 31, 2021, EOG paid cash for property acquisitions of $6 million in the United States. Additionally, during the three months ended March 31, 2021, EOG recognized net losses on asset dispositions of $6 million and received proceeds of approximately $5 million.
During the three months ended March 31, 2020, EOG paid cash for property acquisitions of $44 million in the United States. Additionally, during the three months ended March 31, 2020, EOG recognized net gains on asset dispositions of $16 million, primarily due to the sale of proved properties and non-cash property exchanges of unproved leasehold in Texas, New Mexico and the Rocky Mountain area, and received proceeds of approximately $26 million.
-19-
PART I. FINANCIAL INFORMATION
ITEM 2. MANAGEMENT'S DISCUSSION AND ANALYSIS OF
FINANCIAL CONDITION AND RESULTS OF OPERATIONS
EOG RESOURCES, INC.
Overview
EOG Resources, Inc., together with its subsidiaries (collectively, EOG), is one of the largest independent (non-integrated) crude oil and natural gas companies in the United States with proved reserves in the United States, Trinidad and China. EOG operates under a consistent business and operational strategy that focuses predominantly on maximizing the rate of return on investment of capital by controlling operating and capital costs and maximizing reserve recoveries. Pursuant to this strategy, each prospective drilling location is evaluated by its estimated rate of return. This strategy is intended to enhance the generation of cash flow and earnings from each unit of production on a cost-effective basis, allowing EOG to deliver long-term growth in shareholder value and maintain a strong balance sheet. EOG implements its strategy primarily by emphasizing the drilling of internally generated prospects in order to find and develop low-cost reserves. Maintaining the lowest possible operating cost structure, coupled with efficient and safe operations and robust environmental stewardship practices and performance, is integral in the implementation of EOG's strategy.
Recent Developments. The COVID-19 pandemic and the measures being taken to address and limit the spread of the virus adversely affected the economies and financial markets of the world, resulting in an economic downturn beginning in early 2020 that negatively impacted global demand and prices for crude oil and condensate, natural gas liquids (NGLs) and natural gas. The effects of COVID-19 mitigation efforts, including the wide availability of vaccines, combined with the waning intensity of the pandemic, have resulted in increased demand (and prices) for crude oil and condensate. In the first quarter of 2021, demand and prices for crude oil and condensate returned to near pre-pandemic levels. See ITEM 1A, Risk Factors, of our Annual Report on Form 10-K for the fiscal year ended December 31, 2020, filed on February 25, 2021 (Annual Report), for further discussion.
In early 2021, the members of the Organization of Petroleum Exporting Countries and Russia (OPEC+) met and agreed to taper off certain of their production curtailments (agreed to in April 2020) through March 2021. Subsequent to the meeting, Saudi Arabia announced that it would unilaterally cut its production by an additional one million barrels per day in February 2021 and March 2021. Further, in April 2021, OPEC+ indicated it would continue to ease production curtailments starting in May 2021 as it expected the intensity of the COVID-19 pandemic would subside and containment measures would be scaled back, leading to expected increases in demand for crude oil production in the second half of 2021.
The continuing rebalancing of crude oil demand and supply resulting from improving or stabilizing conditions in certain economies and financial markets of the world, combined with continuing actions taken by OPEC+, have had a positive impact on crude oil prices in the first quarter of 2021.
We will continue to monitor and assess any executive orders or legislative or regulatory actions that could impact the oil and gas industry, to determine the impact on our business and operations, and take appropriate actions where necessary. For related discussion, see ITEM 1, Business – Regulation, ITEM 1A, Risk Factors and ITEM 7, Management's Discussion and Analysis of Financial Condition and Results of Operations - Overview, of our Annual Report.
Commodity Prices. Prices for crude oil and condensate, natural gas liquids (NGLs) and natural gas have historically been volatile. This volatility is expected to continue due to the many uncertainties associated with the world political and economic environment and the global supply of, and demand for, crude oil, NGLs and natural gas and the availability of other energy supplies, the relative competitive relationships of the various energy sources in the view of consumers and other factors.
The market prices of crude oil and condensate, NGLs and natural gas impact the amount of cash generated from EOG's operating activities, which, in turn, impact EOG's financial position and results of operations.
-20-
For the first three months of 2021, the average U.S. New York Mercantile Exchange (NYMEX) crude oil and condensate and natural gas prices were $57.80 per barrel and $2.69 per million British thermal units (MMBtu), respectively, representing increases of 25% and 36%, respectively, from the average NYMEX prices for the same period in 2020. Market prices for NGLs are influenced by the components extracted, including ethane, propane and butane and natural gasoline, among others, and the respective market pricing for each component. In February 2021, EOG realized higher-than-average daily prices on certain days for deliveries of natural gas volumes due to disruptions throughout the United States from Winter Storm Uri.
United States. EOG's efforts to identify plays with large reserve potential have proven to be successful. EOG continues to drill numerous wells in large acreage plays, which in the aggregate have contributed substantially to, and are expected to continue to contribute substantially to, EOG's crude oil and condensate, NGLs and natural gas production. EOG has placed an emphasis on applying its horizontal drilling and completion expertise to unconventional crude oil and, to a lesser extent, liquids-rich natural gas plays.
During the first three months of 2021, EOG continued to focus on increasing drilling, completion and operating efficiencies gained in prior years. Such efficiencies, combined with new innovation, resulted in lower drilling and completion costs. Winter Storm Uri negatively impacted Lease and Well, Transportation and Gathering and Processing Costs in the first quarter of 2021. In addition, EOG continued to evaluate certain potential crude oil and condensate, NGLs and natural gas exploration and development prospects and to look for opportunities to add drilling inventory through leasehold acquisitions, farm-ins, exchanges or tactical acquisitions. On a volumetric basis, as calculated using the ratio of 1.0 barrel of crude oil and condensate or NGLs to 6.0 thousand cubic feet of natural gas, crude oil and condensate and NGLs production accounted for approximately 75% and 77% of EOG's United States production during the first three months of 2021 and 2020, respectively. During the first three months of 2021, EOG's drilling and completion activities occurred primarily in the Delaware Basin play, Eagle Ford play and Rocky Mountain area. EOG's major producing areas in the United States are in New Mexico and Texas. EOG faced interruptions to sales in certain markets due to disruptions throughout the United States from Winter Storm Uri.
Trinidad. In Trinidad, EOG continues to deliver natural gas under existing supply contracts. Several fields in the South East Coast Consortium Block, Modified U(a) Block, Block 4(a), Modified U(b) Block, the Banyan Field and the Sercan Area have been developed and are producing natural gas which is sold to the National Gas Company of Trinidad and Tobago Limited and its subsidiary, and crude oil and condensate which is sold to Heritage Petroleum Company Limited (Heritage).
In March 2021, EOG signed a farmout agreement with Heritage, which allows EOG to earn a 65% working interest in an offshore block located on the South West Coast Block. EOG is currently planning and preparing to drill one net exploratory well in the second half of 2021. EOG continues to make progress on the design and fabrication of a platform and related facilities for our previously-announced discovery in the Modified U(a) Block.
Other International. In the Sichuan Basin, Sichuan Province, China, EOG continues to work with its partner, PetroChina, under a production sharing contract and other related agreements, to ensure uninterrupted production. All natural gas produced from the Baijaochang Field is sold under a long-term contract to PetroChina.
In April 2021, EOG entered into a sale and purchase agreement for the sale of the subsidiary which holds 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 is approximately 25 million cubic feet per day (MMcfd) of natural gas.
In the Sultanate of Oman, a Royal Decree was issued on March 9, 2021, and EOG became a participant in the Exploration and Production Sharing Agreement for Block 49, holding a 50% working interest. EOG's partner in Block 49 completed the drilling and testing of one gross exploratory well. The results are currently being evaluated. EOG continues to plan and prepare for the drilling of two net exploratory wells in Block 36, which are expected to be drilled later in 2021.
EOG continues to evaluate other select crude oil and natural gas opportunities outside the United States, primarily by pursuing exploitation opportunities in countries where indigenous crude oil and natural gas reserves have been identified.
-21-
2021 Capital and Operating Plan. Total anticipated 2021 capital expenditures are estimated to range from approximately $3.7 billion to $4.1 billion, including facilities and gathering, processing and other expenditures, and excluding acquisitions and non-cash transactions. EOG plans to continue to focus a substantial portion of its exploration and development expenditures in its major producing areas in the United States. In particular, EOG will be focused on United States crude oil drilling activity in its Delaware Basin play, Eagle Ford play and Rocky Mountain area where it generates its highest rates-of-return. To further enhance the economics of these plays, EOG expects to continue to improve well performance and lower drilling and completion costs through efficiency gains, new innovation and initiatives to manage procurement and service costs. In addition, EOG expects to spend a portion of its anticipated 2021 capital expenditures on leasing acreage and evaluating new prospects.
In 2021, total crude oil production is expected to remain at fourth quarter 2020 levels. Further, EOG expects to continue to focus on reducing operating costs in 2021 through efficiency improvements.
Management continues to believe EOG has one of the strongest prospect inventories in EOG's history. When it fits EOG's strategy, EOG will make acquisitions that bolster existing drilling programs or offer incremental exploration and/or production opportunities.
Capital Structure. One of management's key strategies is to maintain a strong balance sheet with a consistently below average debt-to-total capitalization ratio as compared to those in EOG's peer group. EOG's debt-to-total capitalization ratio was 20% at March 31, 2021 and 22% at December 31, 2020. As used in this calculation, total capitalization represents the sum of total current and long-term debt and total stockholders' equity.
On February 1, 2021, EOG repaid upon maturity the $750 million aggregate principal amount of its 4.100% Senior Notes due 2021.
At March 31, 2021, EOG maintained a strong financial and liquidity position, including $3.4 billion of cash and cash equivalents and $2.0 billion of availability under its senior unsecured revolving credit facility.
EOG has significant flexibility with respect to financing alternatives, including borrowings under its commercial paper program, bank borrowings, borrowings under its senior unsecured revolving credit facility, joint development agreements and similar agreements and equity and debt offerings.
-22-
Results of Operations
The following review of operations for the three months ended March 31, 2021 and 2020 should be read in conjunction with the Condensed Consolidated Financial Statements of EOG and notes thereto included in this Quarterly Report on Form 10-Q.
Three Months Ended March 31, 2021 vs. Three Months Ended March 31, 2020
Operating Revenues and Other. During the first quarter of 2021, operating revenues decreased $1,024 million, or 22%, to $3,694 million from $4,718 million for the same period of 2020. Total wellhead revenues, which are revenues generated from sales of EOG's production of crude oil and condensate, NGLs and natural gas, for the first quarter of 2021 increased $754 million, or 31%, to $3,190 million from $2,436 million for the same period of 2020. EOG recognized net losses on the mark-to-market of financial commodity derivative contracts of $367 million for the first quarter of 2021 compared to net gains of $1,206 million for the same period of 2020. Gathering, processing and marketing revenues for the first quarter of 2021 decreased $191 million, or 18%, to $848 million from $1,039 million for the same period of 2020. Net losses on asset dispositions were $6 million for the first quarter of 2021 compared to net gains of $16 million for the same period of 2020.
-23-
Wellhead volume and price statistics for the three-month periods ended March 31, 2021 and 2020 were as follows:
| Three Months Ended March 31, | ||||||||||||||
| 2021 | 2020 | |||||||||||||
Crude Oil and Condensate Volumes (MBbld) (1) | ||||||||||||||
| United States | 428.7 | 482.7 | ||||||||||||
| Trinidad | 2.2 | 0.5 | ||||||||||||
Other International (2) | 0.1 | 0.1 | ||||||||||||
| Total | 431.0 | 483.3 | ||||||||||||
Average Crude Oil and Condensate Prices ($/Bbl) (3) | ||||||||||||||
| United States | $ | 58.07 | $ | 46.97 | ||||||||||
| Trinidad | 49.77 | 34.93 | ||||||||||||
Other International (2) | 38.61 | 57.51 | ||||||||||||
| Composite | 58.02 | 46.96 | ||||||||||||
Natural Gas Liquids Volumes (MBbld) (1) | ||||||||||||||
| United States | 124.3 | 161.3 | ||||||||||||
| Total | 124.3 | 161.3 | ||||||||||||
Average Natural Gas Liquids Prices ($/Bbl) (3) | ||||||||||||||
| United States | $ | 28.03 | $ | 10.94 | ||||||||||
| Composite | 28.03 | 10.94 | ||||||||||||
Natural Gas Volumes (MMcfd) (1) | ||||||||||||||
| United States | 1,100 | 1,139 | ||||||||||||
| Trinidad | 217 | 201 | ||||||||||||
Other International (2) | 25 | 38 | ||||||||||||
| Total | 1,342 | 1,378 | ||||||||||||
Average Natural Gas Prices ($/Mcf) (3) | ||||||||||||||
| United States | $ | 5.52 | $ | 1.50 | ||||||||||
| Trinidad | 3.38 | 2.17 | ||||||||||||
Other International (2) | 5.66 | 4.32 | ||||||||||||
| Composite | 5.17 | 1.67 | ||||||||||||
Crude Oil Equivalent Volumes (MBoed) (4) | ||||||||||||||
| United States | 736.4 | 833.8 | ||||||||||||
| Trinidad | 38.5 | 34.0 | ||||||||||||
Other International (2) | 4.0 | 6.3 | ||||||||||||
| Total | 778.9 | 874.1 | ||||||||||||
Total MMBoe (4) | 70.1 | 79.5 | ||||||||||||
(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).
(4)Thousand barrels of oil equivalent per day or million barrels of oil equivalent, as applicable; includes crude oil and condensate, NGLs and natural gas. Crude oil equivalent volumes are determined using a ratio of 1.0 barrel of crude oil and condensate or NGLs to 6.0 thousand cubic feet of natural gas. MMBoe is calculated by multiplying the MBoed amount by the number of days in the period and then dividing that amount by one thousand.
-24-
Wellhead crude oil and condensate revenues for the first quarter of 2021 increased $186 million, or 9%, to $2,251 million from $2,065 million for the same period of 2020. The increase was due to a higher composite average price ($431 million), partially offset by a decrease of 52 MBbld, or 11%, in wellhead crude oil and condensate production ($245 million). Decreased production was primarily in the Eagle Ford. EOG's composite wellhead crude oil and condensate price for the first quarter of 2021 increased 24% to $58.02 per barrel compared to $46.96 per barrel for the same period of 2020.
NGL revenues for the first quarter of 2021 increased $153 million, or 95%, to $314 million from $161 million for the same period of 2020 due to a higher composite average price ($191 million), partially offset by a decrease of 37 MBbld, or 23%, in NGL deliveries ($38 million). Decreased production was primarily in the Permian Basin and the Eagle Ford. EOG's composite NGL price for the first quarter of 2021 increased 156% to $28.03 per barrel compared to $10.94 per barrel for the same period of 2020.
Wellhead natural gas revenues for the first quarter of 2021 increased $415 million, or 198%, to $625 million from $210 million for the same period of 2020. The increase was due to a higher average composite price ($422 million), partially offset by a decrease in natural gas deliveries ($7 million). Natural gas deliveries for the first quarter of 2021 decreased 36 MMcfd, or 3%, compared to the same period of 2020 due primarily to the disposition of the Marcellus Shale assets in the third quarter of 2020 and lower natural gas volumes in South Texas and the Barnett Shale, partially offset by increased production of associated natural gas from the Permian Basin. EOG's composite wellhead natural gas price for the first quarter of 2021 increased 210% to $5.17 per Mcf compared to $1.67 per Mcf for the same period of 2020.
During the first quarter of 2021, EOG recognized net losses on the mark-to-market of financial commodity derivative contracts of $367 million compared to net gains of $1,206 million for the same period of 2020. During the first quarter of 2021, net cash paid for settlements of financial commodity derivative contracts was $30 million compared to net cash received of $84 million for the same period of 2020.
Gathering, processing and marketing revenues are revenues generated from sales of third-party crude oil, NGLs and natural gas, as well as fees associated with gathering third-party natural gas and revenues from sales of EOG-owned sand. Purchases and sales of third-party crude oil and natural gas may be utilized in order to balance firm transportation capacity with production in certain areas and to utilize excess capacity at EOG-owned facilities. EOG sells sand in order to balance the timing of firm purchase agreements with completion operations and to utilize excess capacity at EOG-owned facilities. Marketing costs represent the costs to purchase third-party crude oil, natural gas and sand and the associated transportation costs, as well as costs associated with EOG-owned sand sold to third parties.
Gathering, processing and marketing revenues less marketing costs for the first quarter of 2021 increased $81 million as compared to the same period of 2020 primarily due to higher margins on crude oil marketing activities, partially offset by lower margins on natural gas marketing activities.
-25-
Operating and Other Expenses. For the first quarter of 2021, operating expenses of $2,762 million were $1,898 million lower than the $4,660 million incurred during the first quarter of 2020. The following table presents the costs per barrel of oil equivalent (Boe) for the three-month periods ended March 31, 2021 and 2020:
| Three Months Ended March 31, | |||||||||||
| 2021 | 2020 | ||||||||||
| Lease and Well | $ | 3.85 | $ | 4.14 | |||||||
| Transportation Costs | 2.88 | 2.62 | |||||||||
| Gathering and Processing Costs | 1.98 | 1.62 | |||||||||
| Depreciation, Depletion and Amortization (DD&A) - | |||||||||||
| Oil and Gas Properties | 12.31 | 12.18 | |||||||||
| Other Property, Plant and Equipment | 0.53 | 0.39 | |||||||||
| General and Administrative (G&A) | 1.57 | 1.44 | |||||||||
| Interest Expense, Net | 0.67 | 0.56 | |||||||||
Total (1) | $ | 23.79 | $ | 22.95 | |||||||
(1)Total excludes exploration costs, dry hole costs, impairments, marketing costs and taxes other than income.
The primary factors impacting the cost components of per-unit rates of lease and well, transportation, DD&A and G&A for the three months ended March 31, 2021, compared to the same period of 2020, are set forth below. See "Operating Revenues and Other" above for a discussion of wellhead volumes.
Lease and well expenses include expenses for EOG-operated properties, as well as expenses billed to EOG from other operators where EOG is not the operator of a property. Lease and well expenses can be divided into the following categories: costs to operate and maintain crude oil and natural gas wells, the cost of workovers and lease and well administrative expenses. Operating and maintenance costs include, among other things, pumping services, salt water disposal, equipment repair and maintenance, compression expense, lease upkeep and fuel and power. Workovers are operations to restore or maintain production from existing wells.
Each of these categories of costs individually fluctuates from time to time as EOG attempts to maintain and increase production while maintaining efficient, safe and environmentally responsible operations. EOG continues to increase its operating activities by drilling new wells in existing and new areas. Operating and maintenance costs within these existing and new areas, as well as the costs of services charged to EOG by vendors, fluctuate over time.
Lease and well expenses of $270 million for the first quarter of 2021 decreased $60 million from $330 million for the same prior year period primarily due to decreased operating and maintenance costs ($30 million) and decreased workover expenditures ($21 million), both in the United States. Lease and well expenses decreased in the United States primarily due to decreased operating activities resulting from decreased production, efficiency improvements and service cost reductions.
Transportation costs represent costs associated with the delivery of hydrocarbon products from the lease or an aggregation point on EOG's gathering system to a downstream point of sale. Transportation costs include transportation fees, the cost of compression (the cost of compressing natural gas to meet pipeline pressure requirements), the cost of dehydration (the cost associated with removing water from natural gas to meet pipeline requirements), gathering fees and fuel costs.
Transportation costs of $202 million for the first quarter of 2021 decreased $6 million from $208 million for the same prior year period primarily due to decreased transportation costs in the Eagle Ford ($13 million), partially offset by increased transportation costs in the Permian Basin ($10 million).
-26-
DD&A of the cost of proved oil and gas properties is calculated using the unit-of-production method. EOG's DD&A rate and expense are the composite of numerous individual DD&A group calculations. There are several factors that can impact EOG's composite DD&A rate and expense, such as field production profiles, drilling or acquisition of new wells, disposition of existing wells and reserve revisions (upward or downward) primarily related to well performance, economic factors and impairments. Changes to these factors may cause EOG's composite DD&A rate and expense to fluctuate from period to period. DD&A of the cost of other property, plant and equipment is generally calculated using the straight-line depreciation method over the useful lives of the assets.
DD&A expenses for the first quarter of 2021 decreased $100 million to $900 million from $1,000 million for the same prior year period. DD&A expenses associated with oil and gas properties for the first quarter of 2021 were $106 million lower than the same prior year period. The decrease primarily reflects decreased production in the United States ($119 million), partially offset by higher unit rates in the United States ($9 million). Unit rates in the United States increased primarily due to downward reserve revisions related to lower average crude oil, NGL and natural gas prices used in the reserve estimation process as compared to prior year prices.
G&A expenses of $110 million for the first quarter of 2021 decreased $4 million from $114 million for the same prior year period primarily due to decreased employee-related costs ($2 million) and decreased professional and legal services ($2 million).
Gathering and processing costs represent operating and maintenance expenses and administrative expenses associated with operating EOG's gathering and processing assets as well as natural gas processing fees and certain NGL fractionation fees paid to third parties. EOG pays third parties to process the majority of its natural gas production to extract NGLs.
Gathering and processing costs increased $11 million to $139 million for the first quarter of 2021 compared to $128 million for the same prior year period primarily due to increased operating and maintenance expenses in the Rocky Mountain area ($5 million) and increased gathering and processing G&A costs in the United States ($4 million).
Exploration costs of $33 million for the first quarter of 2021 decreased $7 million from $40 million for the same prior year period due primarily to decreased geological and geophysical expenditures ($4 million) and G&A expenses ($3 million), all in the United States.
Impairments include: amortization of unproved oil and gas property costs as well as impairments of proved oil and gas properties; other property, plant and equipment; and other assets. Unproved properties with acquisition costs that are not individually significant are aggregated, and the portion of such costs estimated to be nonproductive is amortized over the remaining lease term. Unproved properties with individually significant acquisition costs are reviewed individually for impairment. When circumstances indicate that a proved property may be impaired, EOG compares expected undiscounted future cash flows at a DD&A group level to the unamortized capitalized cost of the asset. If the expected undiscounted future cash flows, based on EOG's estimates of (and assumptions regarding) future crude oil, NGLs and natural gas prices, operating costs, development expenditures, anticipated production from proved reserves and other relevant data, are lower than the unamortized capitalized cost, the capitalized cost is reduced to fair value. Fair value is generally calculated by using the Income Approach described in the Fair Value Measurement Topic of the Financial Accounting Standards Board's Accounting Standards Codification. In certain instances, EOG utilizes accepted offers from third-party purchasers as the basis for determining fair value.
-27-
The following table represents impairments for the first quarter of 2021 and 2020 (in millions):
| Three Months Ended March 31, | |||||||||||
| 2021 | 2020 | ||||||||||
| Proved properties | $ | — | $ | 1,385 | |||||||
| Unproved properties | 43 | 57 | |||||||||
| Other assets | — | 71 | |||||||||
| Firm commitment contracts | 1 | 60 | |||||||||
| Total | $ | 44 | $ | 1,573 | |||||||
Impairments of proved properties and other assets in the first quarter of 2020 were primarily due to the decline in commodity prices and were primarily related to legacy and non-core natural gas, crude oil and combo plays in the United States. Impairments of firm commitment contracts in the first quarter of 2020 were a result of the decision to exit the Horn River Basin in Canada.
Taxes other than income include severance/production taxes, ad valorem/property taxes, payroll taxes, franchise taxes and other miscellaneous taxes. Severance/production taxes are generally determined based on wellhead revenues, and ad valorem/property taxes are generally determined based on the valuation of the underlying assets.
Taxes other than income for the first quarter of 2021 increased $58 million to $215 million (6.7% of wellhead revenues) from $157 million (6.5% of wellhead revenues) for the same prior year period. The increase in taxes other than income was primarily due to increased severance/production taxes in the United States ($49 million) and the absence of state severance tax refunds recorded in the first quarter of 2021 ($12 million).
Other income (expense), net for the first quarter of 2021 decreased $22 million compared to the same prior year period primarily due to an increase in deferred compensation expense ($17 million) and decreased interest income ($6 million).
EOG recognized an income tax provision of $204 million for the first quarter of 2021 compared to an income tax provision of $21 million for the first quarter of 2020, primarily due to increased pretax income. The net effective tax rate for the first quarter of 2021 decreased to 23% from 68% for the first quarter of 2020 due mostly to the higher level of pretax income which caused the effective rate to be less sensitive to reconciling items and the absence of certain foreign losses for which tax benefits are not recorded due to valuation allowances.
Capital Resources and Liquidity
Cash Flow. The primary sources of cash for EOG during the three months ended March 31, 2021, were funds generated from operations. The primary uses of cash were funds used in operations; exploration and development expenditures; long-term debt repayments; dividend payments to stockholders; other property, plant and equipment expenditures; and net cash paid for settlements of commodity derivative contracts. During the first three months of 2021, EOG's cash balance increased $59 million to $3,388 million from $3,329 million at December 31, 2020.
Net cash provided by operating activities of $1,870 million for the first three months of 2021 decreased $715 million compared to the same period of 2020 primarily due to an unfavorable change in working capital ($1,478 million) and an increase in net cash paid for settlements of commodity derivative contracts ($114 million), partially offset by an increase in wellhead revenues ($754 million) and an increase in gathering, processing and marketing revenues less marketing costs ($81 million).
Net cash used in investing activities of $821 million for the first three months of 2021 decreased $710 million compared to the same period of 2020 due to a decrease in additions to oil and gas properties ($691 million) and a decrease in additions to other property, plant and equipment ($81 million), partially offset by an unfavorable change in components of working capital associated with investing activities ($41 million) and a decrease in proceeds from the sale of assets ($21 million).
-28-
Net cash used in financing activities of $988 million for the first three months of 2021 included repayments of long-term debt ($750 million), cash dividend payments ($219 million), purchases of treasury stock in connection with stock compensation plans ($10 million) and repayment of finance lease liabilities ($9 million). Net cash used in financing activities of $175 million for the first three months of 2020 included cash dividend payments ($167 million), purchases of treasury stock in connection with stock compensation plans ($5 million) and repayment of finance lease liabilities ($3 million).
Total Expenditures. For the year 2021, EOG's updated budget for exploration and development and other property, plant and equipment expenditures is estimated to range from approximately $3.7 billion to $4.1 billion, excluding acquisitions and non-cash transactions. The table below sets out components of total expenditures for the three-month periods ended March 31, 2021 and 2020 (in millions):
| Three Months Ended March 31, | |||||||||||
| 2021 | 2020 | ||||||||||
| Expenditure Category | |||||||||||
| Capital | |||||||||||
| Exploration and Development Drilling | $ | 733 | $ | 1,313 | |||||||
| Facilities | 82 | 179 | |||||||||
Leasehold Acquisitions (1) | 58 | 45 | |||||||||
Property Acquisitions (2) | 9 | 48 | |||||||||
| Capitalized Interest | 8 | 9 | |||||||||
| Subtotal | 890 | 1,594 | |||||||||
| Exploration Costs | 33 | 40 | |||||||||
| Dry Hole Costs | 11 | — | |||||||||
| Exploration and Development Expenditures | 934 | 1,634 | |||||||||
| Asset Retirement Costs | 17 | 20 | |||||||||
| Total Exploration and Development Expenditures | 951 | 1,654 | |||||||||
Other Property, Plant and Equipment (3) | 116 | 172 | |||||||||
| Total Expenditures | $ | 1,067 | $ | 1,826 | |||||||
(1) Leasehold acquisitions included $22 million and $24 million for the three-month periods ended March 31, 2021 and 2020, respectively, related to non-cash property exchanges.
(2) Property acquisitions included $3 million and $5 million for the three-month periods ended March 31, 2021 and 2020, respectively, related to non-cash property exchanges.
(3) Other property, plant and equipment included $74 million and $49 million of non-cash additions for the three-month periods ended March 31, 2021 and 2020, respectively, primarily related to finance lease transactions for storage facilities.
Exploration and development expenditures of $934 million for the first three months of 2021 were $700 million lower than the same period of 2020 primarily due to decreased exploration and development drilling expenditures in the United States ($575 million) and Trinidad ($11 million), decreased facilities expenditures ($97 million) and decreased property acquisitions ($39 million), partially offset by increased leasehold acquisitions ($12 million). Exploration and development expenditures for the first three months of 2021 of $934 million consisted of $812 million in development drilling and facilities, $105 million in exploration, $9 million in property acquisitions and $8 million in capitalized interest. Exploration and development expenditures for the first three months of 2020 of $1,634 million consisted of $1,465 million in development drilling and facilities, $112 million in exploration, $48 million in property acquisitions and $9 million in capitalized interest.
The level of exploration and development expenditures, including acquisitions, will vary in future periods depending on energy market conditions and other economic factors. EOG believes it has significant flexibility and availability with respect to financing alternatives and the ability to adjust its exploration and development expenditure budget as circumstances warrant. While EOG has certain continuing commitments associated with expenditure plans related to its operations, such commitments are not expected to be material when considered in relation to the total financial capacity of EOG.
-29-
Commodity Derivative Transactions. As more fully discussed in Note 12 to the Consolidated Financial Statements included in EOG's Annual Report on Form 10-K for the year ended December 31, 2020, filed on February 25, 2021, EOG engages in price risk management activities from time to time. These activities are intended to manage EOG's exposure to fluctuations in commodity prices for crude oil, NGLs and natural gas. EOG utilizes financial commodity derivative instruments, primarily price swap, option, swaption, collar and basis swap contracts, as a means to manage this price risk. EOG has not designated any of its financial commodity derivative contracts as accounting hedges and, accordingly, accounts for financial commodity derivative contracts using the mark-to-market accounting method. Under this accounting method, changes in the fair value of outstanding financial instruments are recognized as gains or losses in the period of change and are recorded as Gains (Losses) on Mark-to-Market Commodity Derivative Contracts on the Condensed Consolidated Statements of Income and Comprehensive Income. The related cash flow impact is reflected in Cash Flows from Operating Activities on the Condensed Consolidated Statements of Cash Flows.
The total fair value of EOG's commodity derivative contracts was reflected on the Condensed Consolidated Balance Sheets at March 31, 2021, as a net liability of $195 million.
Commodity Derivative Contracts. Presented below is a comprehensive summary of EOG's financial commodity derivative contracts as of April 29, 2021. Crude oil and NGL volumes are presented in MBbld and prices are presented in $/Bbl. Natural gas volumes are presented in MMBtu per day (MMBtud) and prices are presented in dollars per MMBtu ($/MMBtu).
| Crude Oil Financial Price Swap Contracts | ||||||||||||||||||||
| Contracts Sold | ||||||||||||||||||||
| Period | Settlement Index | Volume (MBbld) | Weighted Average Price ($/Bbl) | |||||||||||||||||
| January 2021 (closed) | NYMEX West Texas Intermediate (WTI) | 151 | $ | 50.06 | ||||||||||||||||
| February - March 2021 (closed) | NYMEX WTI | 201 | 51.29 | |||||||||||||||||
| April - June 2021 | NYMEX WTI | 150 | 51.68 | |||||||||||||||||
| July - September 2021 | NYMEX WTI | 150 | 52.71 | |||||||||||||||||
| Crude Oil Basis Swap Contracts | ||||||||||||||||||||
| Contracts Sold | ||||||||||||||||||||
| Period | Settlement Index | Volume (MBbld) | Weighted Average Price Differential ($/Bbl) | |||||||||||||||||
| February 2021 (closed) | NYMEX WTI Roll Differential (1) | 30 | $ | 0.11 | ||||||||||||||||
| March - May 2021 (closed) | NYMEX WTI Roll Differential (1) | 125 | 0.17 | |||||||||||||||||
| June - December 2021 | NYMEX WTI Roll Differential (1) | 125 | 0.17 | |||||||||||||||||
| January - 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.
-30-
| NGL Financial Price Swap Contracts | ||||||||||||||||||||
| Contracts Sold | ||||||||||||||||||||
| Period | Settlement Index | Volume (MBbld) | Weighted Average Price ($/Bbl) | |||||||||||||||||
| January - March 2021 (closed) | Mont Belvieu Propane (non-Tet) | 15 | $ | 29.44 | ||||||||||||||||
| April - December 2021 | Mont Belvieu Propane (non-Tet) | 15 | 29.44 | |||||||||||||||||
| Natural Gas Financial Price Swap Contracts | ||||||||||||||||||||||||||||||||
| Contracts Sold | Contracts Purchased | |||||||||||||||||||||||||||||||
| Period | Settlement Index | Volume (MMBtud in thousands) | Weighted Average Price ($/MMBtu) | Volume (MMBtud in thousands) | Weighted Average Price ($/MMBtu) | |||||||||||||||||||||||||||
| January - March 2021 (closed) | NYMEX Henry Hub | 500 | $ | 2.99 | 500 | $ | 2.43 | |||||||||||||||||||||||||
| April - May 2021 (closed) | NYMEX Henry Hub | 500 | 2.99 | 570 | 2.81 | |||||||||||||||||||||||||||
| June - September 2021 | NYMEX Henry Hub | 500 | 2.99 | 570 | 2.81 | |||||||||||||||||||||||||||
| October - December 2021 | NYMEX Henry Hub | 500 | 2.99 | 500 | 2.83 | |||||||||||||||||||||||||||
January - December 2022 (closed) (1) | NYMEX Henry Hub | 20 | 2.75 | — | — | |||||||||||||||||||||||||||
| April - May 2021 (closed) | Japan Korea Marker (JKM) | 70 | 6.65 | — | — | |||||||||||||||||||||||||||
| June - September 2021 | JKM | 70 | 6.65 | — | — | |||||||||||||||||||||||||||
_________________
(1) In January 2021, EOG executed the early termination provision granting EOG the right to terminate all of its open 2022 natural gas price swap contracts. EOG received net cash of $0.6 million for the settlement of these contracts.
Information Regarding Forward-Looking Statements
This Quarterly Report on Form 10-Q includes forward-looking statements within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended. All statements, other than statements of historical facts, including, among others, statements and projections regarding EOG's future financial position, operations, performance, business strategy, goals, returns and rates of return, budgets, reserves, levels of production, capital expenditures, costs and asset sales, statements regarding future commodity prices and statements regarding the plans and objectives of EOG's management for future operations, are forward‐looking statements. EOG typically uses words such as "expect," "anticipate," "estimate," "project," "strategy," "intend," "plan," "target," "aims," "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, or pay and/or increase dividends are forward‐looking statements. Forward-looking statements are not guarantees of performance. Although EOG believes the expectations reflected in its forward-looking statements are reasonable and are based on reasonable assumptions, no assurance can be given that these assumptions are accurate or that any of these expectations will be achieved (in full or at all) or will prove to have been correct. Moreover, EOG's forward-looking statements may be affected by known, unknown or currently unforeseen risks, events or circumstances that may be outside EOG's control. Important factors that could cause EOG's actual results to differ materially from the expectations reflected in EOG's forward-looking statements include, among others:
•the timing, extent and duration of changes in prices for, supplies of, and demand for, crude oil and condensate, natural gas liquids, natural gas and related commodities;
•the extent to which EOG is successful in its efforts to acquire or discover additional reserves;
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•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, 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
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•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.
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PART I. FINANCIAL INFORMATION
ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
EOG RESOURCES, INC.
EOG's exposure to commodity price risk, interest rate risk and foreign currency exchange rate risk is discussed in (i) the "Commodity Derivative Transactions," "Financing," "Foreign Currency Exchange Rate Risk" and "Outlook" sections of "Management's Discussion and Analysis of Financial Condition and Results of Operations - Capital Resources and Liquidity" on pages 45 through 53 of EOG's Annual Report on Form 10-K for the year ended December 31, 2020, filed on February 25, 2021 (EOG's 2020 Annual Report); and (ii) Note 12, "Risk Management Activities," to EOG's Consolidated Financial Statements on pages F-31 through F-36 of EOG's 2020 Annual Report. There have been no material changes in this information. For additional information regarding EOG's financial commodity derivative contracts and physical commodity contracts, see (i) Note 12, "Risk Management Activities," to EOG's Condensed Consolidated Financial Statements in this Quarterly Report on Form 10-Q; (ii) "Management's Discussion and Analysis of Financial Condition and Results of Operations - Results of Operations - Operating Revenues" in this Quarterly Report on Form 10-Q; and (iii) "Management's Discussion and Analysis of Financial Condition and Results of Operations - Capital Resources and Liquidity - Commodity Derivative Transactions" in this Quarterly Report on Form 10-Q.
ITEM 4. CONTROLS AND PROCEDURES
EOG RESOURCES, INC.
Disclosure Controls and Procedures. EOG's management, with the participation of EOG's principal executive officer and principal financial officer, evaluated the effectiveness of EOG's disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e) promulgated under the Securities Exchange Act of 1934, as amended (Exchange Act)) as of the end of the period covered by this Quarterly Report on Form 10-Q (Evaluation Date). Based on this evaluation, EOG's principal executive officer and principal financial officer have concluded that EOG's disclosure controls and procedures were effective as of the Evaluation Date in ensuring that information that is required to be disclosed in the reports EOG files or furnishes under the Exchange Act is (i) recorded, processed, summarized and reported within the time periods specified in the United States Securities and Exchange Commission's rules and forms and (ii) accumulated and communicated to EOG's management, as appropriate, to allow timely decisions regarding required disclosure.
Internal Control Over Financial Reporting. There were no changes in EOG's internal control over financial reporting (as defined in Rules 13a-15(f) and 15d-15(f) promulgated under the Exchange Act) that occurred during the quarterly period covered by this Quarterly Report on Form 10-Q that have materially affected, or are reasonably likely to materially affect, EOG's internal control over financial reporting.
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PART II. OTHER INFORMATION
EOG RESOURCES, INC.
ITEM 1. LEGAL PROCEEDINGS
See Part I, Item 1, Note 8 to Condensed Consolidated Financial Statements, which is incorporated herein by reference.
Item 103 of Regulation S-K promulgated under the Securities Exchange Act of 1934, as amended, requires disclosure regarding certain proceedings arising under federal, state or local environmental laws when a governmental authority is a party to the proceedings and such proceedings involve potential monetary sanctions that EOG reasonably believes will exceed a specified threshold. Pursuant to recent amendments to this item, EOG will be using a threshold of $1 million for purposes of determining whether disclosure of any such proceedings is required. EOG believes proceedings under this threshold are not material to EOG's business and financial condition. Applying this threshold, there are no environmental proceedings to disclose for the quarter ended March 31, 2021.
ITEM 2. UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS
The following table sets forth, for the periods indicated, EOG's share repurchase activity:
| Period | Total Number of Shares Purchased (1) | Average Price Paid Per Share | Total Number of Shares Purchased as Part of Publicly Announced Plans or Programs | Maximum Number of Shares that May Yet Be Purchased Under The Plans or Programs (2) | ||||||||||||||||||||||
| January 1, 2021 - January 31, 2021 | 6,614 | $ | 51.36 | — | 6,386,200 | |||||||||||||||||||||
| February 1, 2021 - February 28, 2021 | 23,168 | 63.20 | — | 6,386,200 | ||||||||||||||||||||||
| March 1, 2021 - March 31, 2021 | 112,488 | 74.45 | — | 6,386,200 | ||||||||||||||||||||||
| Total | 142,270 | 71.55 | — | |||||||||||||||||||||||
(1)The 142,270 total shares for the quarter ended March 31, 2021, consist solely of shares that were withheld by or returned to EOG (i) in satisfaction of tax withholding obligations that arose upon the exercise of employee stock options or stock-settled stock appreciation rights or the vesting of restricted stock, restricted stock unit, or performance unit grants or (ii) in payment of the exercise price of employee stock options. These shares do not count against the 10 million aggregate share repurchase authorization by EOG's Board of Directors (Board) discussed below.
(2)In September 2001, the Board authorized the repurchase of up to 10 million shares of EOG's common stock. During the first quarter of 2021, EOG did not repurchase any shares under the Board-authorized repurchase program. EOG last repurchased shares under this program in March 2003.
ITEM 4. MINE SAFETY DISCLOSURES
The information concerning mine safety violations and other regulatory matters required by Section 1503(a) of the Dodd-Frank Wall Street Reform and Consumer Protection Act and Item 104 of Regulation S-K (17 CFR 229.104) is included in Exhibit 95 to this Quarterly Report on Form 10-Q.
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ITEM 6. EXHIBITS
Exhibit No. | Description | |||||||
| 3.1(a) | - | |||||||
| 3.1(b) | - | |||||||
| 3.1(c) | - | |||||||
| 3.1(d) | - | |||||||
| 3.1(e) | - | |||||||
| 3.1(f) | - | |||||||
| 3.1(g) | - | |||||||
| 3.1(h) | - | |||||||
| 3.1(i) | - | |||||||
| 3.1(j) | - | |||||||
| 3.1(k) | - | |||||||
| 3.1(l) | - | |||||||
| 3.1(m) | - | |||||||
| 3.1(n) | - | |||||||
| 3.2 | - | |||||||
| 10.1 | - | |||||||
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| Exhibit No. | Description | |||||||
| 10.2 | - | |||||||
| 31.1 | - | |||||||
| 31.2 | - | |||||||
| 32.1 | - | |||||||
| 32.2 | - | |||||||
| 95 | - | |||||||
| 101.INS | - | Inline XBRL Instance Document - the instance document does not appear in the Interactive Data File because its XBRL tags are embedded within the Inline XBRL document. | ||||||
| *101.SCH | - | Inline XBRL Schema Document. | ||||||
| *101.CAL | - | Inline XBRL Calculation Linkbase Document. | ||||||
| *101.DEF | - | Inline XBRL Definition Linkbase Document. | ||||||
| *101.LAB | - | Inline XBRL Label Linkbase Document. | ||||||
| *101.PRE | - | Inline XBRL Presentation Linkbase Document. | ||||||
| 104 | - | Cover Page Interactive Data File (formatted as Inline XBRL and contained in Exhibit 101). | ||||||
*Attached as Exhibit 101 to this report are the following documents formatted in XBRL (Extensible Business Reporting Language): (i) the Condensed Consolidated Statements of Income and Comprehensive Income - Three Months ended March 31, 2021 and 2020, (ii) the Condensed Consolidated Balance Sheets - March 31, 2021 and December 31, 2020, (iii) the Condensed Consolidated Statements of Stockholders' Equity - Three Months Ended March 31, 2021 and 2020, (iv) the Condensed Consolidated Statements of Cash Flows - Three Months Ended March 31, 2021 and 2020 and (v) the Notes to Condensed Consolidated Financial Statements.
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SIGNATURES
Pursuant to the requirements of the Securities Exchange Act of 1934, as amended, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.
| EOG RESOURCES, INC. | |||||||||||
| (Registrant) | |||||||||||
| Date: | May 6, 2021 | By: | /s/ TIMOTHY K. DRIGGERS Timothy K. Driggers Executive Vice President and Chief Financial Officer (Principal Financial Officer and Duly Authorized Officer) | ||||||||
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