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 ~~September 30, 2019~~March 31, 2020

☐ 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	~~581,764,095~~582,045,941	(as of ~~October 25, 2019)~~April 29, 2020)

EOG RESOURCES, INC.

TABLE OF CONTENTS



PART I.	FINANCIAL INFORMATION		Page No.

	ITEM 1.	Financial Statements (Unaudited)

		Condensed Consolidated Statements of Income and Comprehensive Income - Three Months Ended March 31, 2020 and ~~Nine Months Ended September 30,~~ 2019 ~~and 2018~~	3

		Condensed Consolidated Balance Sheets - ~~September 30, 2019~~March 31, 2020 and December 31, ~~2018~~2019	4

		Condensed Consolidated Statements of Stockholders' Equity - Three Months Ended March 31, 2020 and ~~Nine Months Ended September 30,~~ 2019 ~~and 2018~~	5

		Condensed Consolidated Statements of Cash Flows - ~~Nine~~Three Months Ended ~~September 30,~~March 31, 2020 and 2019 ~~and 2018~~	76

		Notes to Condensed Consolidated Financial Statements	87

	ITEM 2.	Management's Discussion and Analysis of Financial Condition and Results of Operations	21

	ITEM 3.	Quantitative and Qualitative Disclosures About Market Risk	36

	ITEM 4.	Controls and Procedures	36

PART II.	OTHER INFORMATION

	ITEM 1.	Legal Proceedings	37

	ITEM 1A.	Risk Factors	37

	ITEM 2.	Unregistered Sales of Equity Securities and Use of Proceeds	37

	ITEM 4.	Mine Safety Disclosures	3738

	ITEM 6.	Exhibits	3839

SIGNATURES			4041

PART I. FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS

EOG RESOURCES, INC.

CONDENSED CONSOLIDATED STATEMENTS OF INCOME AND COMPREHENSIVE INCOME

(In Thousands, Except Per Share Data)

(Unaudited)


	Three Months Ended September 30,						Nine Months Ended September 30,						Three Months Ended March 31,
	2019			2018			2019			2018			2020		2019
Operating Revenues and Other
Crude Oil and Condensate	$	2,418,989		$	2,655,278		$	7,148,258		$	7,134,114		$	2,065,498	$	2,200,403
Natural Gas Liquids	164,736			353,704			569,748			861,473			160,535		218,638
Natural Gas	269,625			311,713			874,489			912,324			209,764		334,972
Gains (Losses) on Mark-to-Market Commodity Derivative Contracts	85,902			(52,081		)	242,622			(297,735		)	1,205,773		(20,580		)
Gathering, Processing and Marketing	1,334,450			1,360,992			4,121,490			3,899,250			1,038,646		1,285,654
Gains (Losses) on Asset Dispositions, Net	(523		)	115,944			3,650			94,658			16,460		(3,836		)
Other, Net	30,276			36,074			99,470			96,779			21,016		43,391
Total	4,303,455			4,781,624			13,059,727			12,700,863			4,717,692		4,058,642
Operating Expenses
Lease and Well	348,883			321,568			1,032,455			936,236			329,659		336,291
Transportation Costs	199,365			196,027			549,988			550,781			208,296		176,522
Gathering and Processing Costs	127,549			114,063			351,487			324,577			128,482		111,295
Exploration Costs	34,540			32,823			103,386			115,137			39,677		36,324
Dry Hole Costs	24,138			358			28,001			5,260			372		94
Impairments	105,275			44,617			289,761			160,934			1,572,935		72,356
Marketing Costs	1,343,293			1,326,974			4,114,265			3,853,827			1,108,993		1,270,057
Depreciation, Depletion and Amortization	953,597			918,180			2,790,496			2,515,445			1,000,060		879,595
General and Administrative	135,758			111,284			364,210			310,065			114,273		106,672
Taxes Other Than Income	203,098			209,043			600,418			582,395			157,360		192,906
Total	3,475,496			3,274,937			10,224,467			9,354,657			4,660,107		3,182,112
Operating Income	827,959			1,506,687			2,835,260			3,346,206			57,585		876,530
Other Income (Expense), Net	9,118			3,308			23,233			(4,516		)
Other Income, Net													18,108		5,612
Income Before Interest Expense and Income Taxes	837,077			1,509,995			2,858,493			3,341,690			75,693		882,142
Interest Expense, Net	39,620			63,632			144,434			189,032			44,690		54,906
Income Before Income Taxes	797,457			1,446,363			2,714,059			3,152,658			31,003		827,236
Income Tax Provision	182,335			255,411			615,670			626,386			21,190		191,810
Net Income	$	615,122		$	1,190,952		$	2,098,389		$	2,526,272		$	9,813	$	635,426
Net Income Per Share
Basic	$	1.06		$	2.06		$	3.63		$	4.38		$	0.02	$	1.10
Diluted	$	1.06		$	2.05		$	3.61		$	4.35		$	0.02	$	1.10
Average Number of Common Shares
Basic	577,839			577,254			577,498			576,431			578,462		577,207
Diluted	581,271			581,559			581,190			580,442			580,283		580,222
Comprehensive Income
Net Income	$	615,122		$	1,190,952		$	2,098,389		$	2,526,272		$	9,813	$	635,426
Other Comprehensive Income (Loss)
Foreign Currency Translation Adjustments	833			(1,952		)	(2,616		)	(179		)	1,341		(1,784		)
Other, Net of Tax	6			6			18			18			6		6
Other Comprehensive Income (Loss)	839			(1,946		)	(2,598		)	(161		)	1,347		(1,778		)
Comprehensive Income	$	615,961		$	1,189,006		$	2,095,791		$	2,526,111		$	11,160	$	633,648

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

EOG RESOURCES, INC.

CONDENSED CONSOLIDATED BALANCE SHEETS

(In Thousands, Except Share Data)

(Unaudited)


	September 30, 2019			December 31, 2018			March 31, 2020			December 31, 2019
ASSETS
Current Assets
Cash and Cash Equivalents	$	1,583,105		$	1,555,634		$	2,906,852		$	2,027,972
Accounts Receivable, Net	1,927,996			1,915,215			1,449,637			2,001,658
Inventories	778,120			859,359			662,398			767,297
Assets from Price Risk Management Activities	122,627			23,806			932,928			1,299
Income Taxes Receivable	135,680			427,909			309,328			151,665
Other	272,203			275,467			229,906			323,448
Total	4,819,731			5,057,390			6,491,049			5,273,339
Property, Plant and Equipment
Oil and Gas Properties (Successful Efforts Method)	61,620,033			57,330,016			64,046,355			62,830,415
Other Property, Plant and Equipment	4,394,486			4,220,665			4,648,834			4,472,246
Total Property, Plant and Equipment	66,014,519			61,550,681			68,695,189			67,302,661
Less: Accumulated Depreciation, Depletion and Amortization	(35,810,197		)	(33,475,162		)	(39,001,135		)	(36,938,066		)
Total Property, Plant and Equipment, Net	30,204,322			28,075,519			29,694,054			30,364,595
Deferred Income Taxes	1,998			777			2,558			2,363
Other Assets	1,516,218			800,788			1,446,423			1,484,311
Total Assets	$	36,542,269		$	33,934,474		$	37,634,084		$	37,124,608
LIABILITIES AND STOCKHOLDERS' EQUITY
Current Liabilities
Accounts Payable	$	2,395,080		$	2,239,850		$	2,892,320		$	2,429,127
Accrued Taxes Payable	302,774			214,726			200,240			254,850
Dividends Payable	166,215			126,971			216,933			166,273
Liabilities from Price Risk Management Activities							—			20,194
Current Portion of Long-Term Debt	1,014,200			913,093			519,017			1,014,524
Current Portion of Operating Lease Liabilities	384,348			—			322,367			369,365
Other	211,096			233,724			154,134			232,655
Total	4,473,713			3,728,364			4,305,011			4,486,988

Long-Term Debt	4,163,115			5,170,169			4,703,152			4,160,919
Other Liabilities	1,858,357			1,258,355			2,064,175			1,789,884
Deferred Income Taxes	4,922,804			4,413,398			5,091,071			5,046,101
Commitments and Contingencies (Note 8)

Stockholders' Equity
Common Stock, $0.01 Par, 1,280,000,000 Shares Authorized and 582,066,483 Shares Issued at September 30, 2019 and 580,408,117 Shares Issued at December 31, 2018	205,821			205,804
Common Stock, $0.01 Par, 1,280,000,000 Shares Authorized and 582,356,329 Shares Issued at March 31, 2020 and 582,213,016 Shares Issued at December 31, 2019							205,824			205,822
Additional Paid in Capital	5,769,073			5,658,794			5,852,821			5,817,475
Accumulated Other Comprehensive Loss	(3,689		)	(1,358		)	(3,305		)	(4,652		)
Retained Earnings	15,179,381			13,543,130			15,440,142			15,648,604
Common Stock Held in Treasury, 289,903 Shares at September 30, 2019 and 385,042 Shares at December 31, 2018	(26,306		)	(42,182		)
Common Stock Held in Treasury, 319,162 Shares at March 31, 2020 and 298,820 Shares at December 31, 2019							(24,807		)	(26,533		)
Total Stockholders' Equity	21,124,280			19,364,188			21,470,675			21,640,716
Total Liabilities and Stockholders' Equity	$	36,542,269		$	33,934,474		$	37,634,084		$	37,124,608

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

EOG RESOURCES, INC.

CONDENSED CONSOLIDATED STATEMENTS OF STOCKHOLDERS' EQUITY

(In Thousands, 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			Common Stock		Additional Paid In Capital			Accumulated Other Comprehensive Income (Loss)			Retained Earnings			Common Stock Held In Treasury			Total Stockholders' Equity
Balance at June 30, 2019	$	205,809	$	5,729,318		$	(4,528	)	$	14,731,609		$	(31,932	)	$	20,630,276
Balance at December 31, 2019																		$	205,822	$	5,817,475		$	(4,652	)	$	15,648,604		$	(26,533	)	$	21,640,716
Net Income	—		—			—			615,122			—			615,122			—		—			—			9,813			—			9,813
Common Stock Issued Under Stock Plans	—		—			—			—			—			—			—		(14		)	—			—			—			(14		)
Common Stock Dividends Declared, $0.2875 Per Share	—		—			—			(167,350		)	—			(167,350		)
Common Stock Dividends Declared, $0.375 Per Share																		—		—			—			(218,275		)	—			(218,275		)
Other Comprehensive Income	—		—			839			—			—			839			—		—			1,347			—			—			1,347
Change in Treasury Stock - Stock Compensation Plans, Net	—		(12,220		)	—			—			(759		)	(12,979		)	—		(376		)	—			—			(4,199		)	(4,575		)
Restricted Stock and Restricted Stock Units, Net	12		(2,270		)	—			—			2,258			—			2		(3,956		)	—			—			3,954			—
Stock-Based Compensation Expenses	—		54,670			—			—			—			54,670			—		40,072			—			—			—			40,072
Treasury Stock Issued as Compensation	—		(425		)	—			—			4,127			3,702			—		(380		)	—			—			1,971			1,591
Balance at September 30, 2019	$	205,821	$	5,769,073		$	(3,689	)	$	15,179,381		$	(26,306	)	$	21,124,280
Balance at March 31, 2020																		$	205,824	$	5,852,821		$	(3,305	)	$	15,440,142		$	(24,807	)	$	21,470,675

Common
Stock

Additional
Paid In
Capital

Accumulated
Other
Comprehensive
Income (Loss)

Retained
Earnings

Common
Stock
Held In
Treasury

Total
Stockholders'
Equity
Balance at June 30, 2018 $ 205,796
$ 5,591,643
$ (17,512 ) $ 11,714,656
$ (42,189 ) $ 17,452,394
Net Income —
—
—
1,190,952
—
1,190,952
Common Stock Issued Under Stock Plans 2
(2 ) —
—
—
—
Common Stock Dividends Declared, $0.22 Per Share —
—
—
(127,504 ) —
(127,504 )
Other Comprehensive Loss —
—
(1,946 ) —
—
(1,946 )
Change in Treasury Stock - Stock Compensation Plans, Net —
(7,034 ) —
—
(18,550 ) (25,584 )
Restricted Stock and Restricted Stock Units, Net 5
(7,548 ) —
—
7,543
—
Stock-Based Compensation Expenses —
49,001
—
—
—
49,001
Treasury Stock Issued as Compensation —
199
—
—
958
1,157
Balance at September 30, 2018 $ 205,803
$ 5,626,259
$ (19,458 ) $ 12,778,104
$ (52,238 ) $ 18,538,470

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

~~EOG RESOURCES, INC.~~

~~CONDENSED CONSOLIDATED STATEMENTS OF STOCKHOLDERS' EQUITY~~

~~(In Thousands, 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, 2018 $ 205,804
$ 5,658,794
$ (1,358 ) $ 13,543,130
$ (42,182 ) $ 19,364,188
Net Income —
—
—
2,098,389
—
2,098,389
Common Stock Issued Under Stock Plans —
—
—
—
—
—
Common Stock Dividends Declared, $0.795 Per Share —
—
—
(461,871 ) —
(461,871 )
Other Comprehensive Loss —
—
(2,598 ) —
—
(2,598 )
Change in Treasury Stock - Stock Compensation Plans, Net —
(19,295 ) —
—
6,719
(12,576 )
Restricted Stock and Restricted Stock Units, Net 17
(1,886 ) —
—
1,869
—
Stock-Based Compensation Expenses —
132,323
—
—

132,323
Treasury Stock Issued as Compensation —
(863 ) —
—
7,288
6,425
Cumulative Effect of Adoption of ASU 2018-02, "Income Statement - Reporting Comprehensive Income (Topic 220)" —
—
267
(267 ) —
—
Balance at September 30, 2019 $ 205,821
$ 5,769,073
$ (3,689 ) $ 15,179,381
$ (26,306 ) $ 21,124,280


	Common Stock		Additional Paid In Capital			Accumulated Other Comprehensive Income (Loss)			Retained Earnings			Common Stock Held In Treasury			Total Stockholders' Equity			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, 2017	$	205,788	$	5,536,547		$	(19,297	)	$	10,593,533		$	(33,298	)	$	16,283,273
Balance at December 31, 2018																		$	205,804	$	5,658,794		$	(1,358	)	$	13,543,130		$	(42,182	)	$	19,364,188
Net Income	—		—			—			2,526,272			—			2,526,272			—		—			—			635,426			—			635,426
Common Stock Issued Under Stock Plans	7		(7		)	—			—			—			—			—		(1,235		)	—			—			1,694			459
Common Stock Dividends Declared, $0.590 Per Share	—		—			—			(341,701		)	—			(341,701		)
Common Stock Dividends Declared, $0.22 Per Share																		—		—			—			(127,613		)	—			(127,613		)
Other Comprehensive Loss	—		—			(161		)	—			—			(161		)	—		—			(1,778		)	—			—			(1,778		)
Change in Treasury Stock - Stock Compensation Plans, Net	—		(23,458		)	—			—			(23,002		)	(46,460		)	—		(5		)	—			—			(6,243		)	(6,248		)
Restricted Stock and Restricted Stock Units, Net	8		(3,421		)	—			—			3,413			—			3		(1,404		)	—			—			1,401			—
Stock-Based Compensation Expenses	—		116,290			—			—			—			116,290			—		39,087			—			—			—			39,087
Treasury Stock Issued as Compensation	—		308			—			—			649			957			—		(40		)	—			—			316			276
Balance at September 30, 2018	$	205,803	$	5,626,259		$	(19,458	)	$	12,778,104		$	(52,238	)	$	18,538,470
Cumulative Effect of Adoption of ASU 2018-2, "Income Statement - Reporting Comprehensive Income (Topic 220)"																		—		—			267			(267		)	—			—
Balance at March 31, 2019																		$	205,807	$	5,695,197		$	(2,869	)	$	14,050,676		$	(45,014	)	$	19,903,797

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

EOG RESOURCES, INC.

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(In Thousands)

(Unaudited)


	Nine Months Ended September 30,						Three Months Ended March 31,
	2019			2018			2020			2019
Cash Flows from Operating Activities
Reconciliation of Net Income to Net Cash Provided by Operating Activities:
Net Income	$	2,098,389		$	2,526,272		$	9,813		$	635,426
Items Not Requiring (Providing) Cash
Depreciation, Depletion and Amortization	2,790,496			2,515,445			1,000,060			879,595
Impairments	289,761			160,934			1,572,935			72,356
Stock-Based Compensation Expenses	132,323			116,290			40,072			39,087
Deferred Income Taxes	508,576			681,702			44,774			106,324
Gains on Asset Dispositions, Net	(3,650		)	(94,658		)
(Gains) Losses on Asset Dispositions, Net							(16,460		)	3,836
Other, Net	4,155			15,314			(8,815		)	2,952
Dry Hole Costs	28,001			5,260			372			94
Mark-to-Market Commodity Derivative Contracts
Total (Gains) Losses	(242,622		)	297,735			(1,205,773		)	20,580
Net Cash Received from (Payments for) Settlements of Commodity Derivative Contracts	139,708			(180,228		)
Net Cash Received from Settlements of Commodity Derivative Contracts							84,373			20,846
Other, Net	1,215			1,652			(355		)	976
Changes in Components of Working Capital and Other Assets and Liabilities
Accounts Receivable	(5,855		)	(553,529		)	722,163			(308,996		)
Inventories	55,598			(286,817		)	102,670			(18,979		)
Accounts Payable	134,253			537,525			433,558			194,082
Accrued Taxes Payable	88,047			(36,891		)	(54,605		)	114,998
Other Assets	394,573			(103,334		)	58,296			(6,935		)
Other Liabilities	(18,315		)	(14,776		)	(66,078		)	(54,092		)
Changes in Components of Working Capital Associated with Investing and Financing Activities	(38,677		)	95,484
Changes in Components of Working Capital Associated with Investing Activities							(132,082		)	(94,381		)
Net Cash Provided by Operating Activities	6,355,976			5,683,380			2,584,918			1,607,769
Investing Cash Flows
Additions to Oil and Gas Properties	(4,866,882		)	(4,571,932		)	(1,566,051		)	(1,939,473		)
Additions to Other Property, Plant and Equipment	(187,350		)	(202,384		)	(122,775		)	(60,963		)
Proceeds from Sales of Assets	35,409			11,582			25,801			15,049
Other Investing Activities	—			(19,993		)
Changes in Components of Working Capital Associated with Investing Activities	38,677			(95,541		)	132,082			94,381
Net Cash Used in Investing Activities	(4,980,146		)	(4,878,268		)	(1,530,943		)	(1,891,006		)
Financing Cash Flows
Long-Term Debt Repayments	(900,000		)	—
Dividends Paid	(420,851		)	(311,075		)	(167,058		)	(127,546		)
Treasury Stock Purchased	(22,238		)	(58,558		)	(4,655		)	(6,248		)
Proceeds from Stock Options Exercised and Employee Stock Purchase Plan	9,558			12,098			66			403
Debt Issuance Costs	(5,016		)	—
Repayment of Finance Lease Liabilities	(9,638		)	(5,052		)	(3,621		)	(3,190		)
Changes in Components of Working Capital Associated with Financing Activities	—			57
Net Cash Used in Financing Activities	(1,348,185		)	(362,530		)	(175,268		)	(136,581		)
Effect of Exchange Rate Changes on Cash	(174		)	(2,678		)	173			(6		)
Increase in Cash and Cash Equivalents	27,471			439,904
Increase (Decrease) in Cash and Cash Equivalents							878,880			(419,824		)
Cash and Cash Equivalents at Beginning of Period	1,555,634			834,228			2,027,972			1,555,634
Cash and Cash Equivalents at End of Period	$	1,583,105		$	1,274,132		$	2,906,852		$	1,135,810

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

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, ~~2018,~~2019, filed on February ~~26,~~27, 2020 (EOG's 2019 ~~(EOG's 2018~~ Annual Report).

The preparation of financial statements in conformity with U.S. GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates. The operating results for the three ~~and nine~~ months ended ~~September 30, 2019,~~March 31, 2020, are not necessarily indicative of the results to be expected for the full year.

Effective January 1, ~~2019,~~2020, EOG adopted the provisions of Accounting Standards Update (ASU) ~~2016-02, "Leases (Topic 842)"~~2016-13, "Measurement of Credit Losses on Financial Instruments" (ASU ~~2016-02)~~2016-13). ASU ~~2016-02~~2016-13 changes the impairment model for financial assets and certain other ~~related ASUs require~~instruments by requiring entities to adopt a forward-looking expected loss model that lessees recognize a right-of-use (ROU) asset and related lease liability, representing the obligation to make lease payments for certain lease transactions, on the Condensed Consolidated Balance Sheets and disclose additional leasing information.

will result in earlier recognition of credit losses. EOG elected to adopt ASU ~~2016-02 and other related ASUs~~2016-13 using the modified retrospective approach with a cumulative-effect adjustment to ~~the opening balance of~~ retained earnings as of the effective date. Financial results reported in periods prior to January 1, ~~2019,~~2020, are unchanged. ~~Additionally,~~ EOG ~~elected~~assessed its applicable financial assets, which are primarily its accounts receivable from hydrocarbon sales and joint interest billings to third-party companies, including foreign state-owned entities in the package of practical expedients within ASU 2016-02 that allows an entity to not reassess prior to the effective date (i) whether any expired or existing contracts are or contain leases, (ii) the lease classification for any expired or existing leases, or (iii) initial direct costs for any existing leases, butoil and gas industry. Based on its assessment and various potential remedies ensuring collection, EOG did not elect the practical expedient of hindsight when determining the lease term of existing contracts at the effective date. EOG also elected the practical expedient under ASU 2018-01, "Leases (Topic 842) - Land Easement Practical Expedient for Transition to Topic 842," and did not evaluate existing or expired land easements not previously accounted for as leases prior to the January 1, 2019 effective date. There was norecord an impact to retained earnings upon adoption and expects current and future credit losses to be immaterial. EOG continues to monitor the credit risk from third-party companies to determine if expected credit losses may become material.

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 ~~2016-02~~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.

In December 2019, the FASB issued ASU 2019-12, "Income Taxes (Topic 740) Simplifying the Accounting for Income Taxes" (ASU 2019-12), which amends certain aspects of accounting for income taxes. ASU 2019-12 removes specific exceptions within existing U.S. GAAP related to the incremental approach for intraperiod tax allocation and 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. ASU 2019-12 is effective for interim and annual periods beginning after December 15, 2020, and early adoption is permitted. EOG is continuing to evaluate the provisions of ASU 2019-12 and has not determined the full impact on its consolidated financial statements and related ~~ASUs. See Note 14.~~disclosures.

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 ~~2018~~2019 Annual Report, EOG maintains various stock-based compensation plans. Stock-based compensation expense is included on the Condensed Consolidated Statements of Income and Comprehensive Income based upon the job function of the employees receiving the grants as follows (in millions):


	Three Months Ended September 30,				Nine Months Ended September 30,				Three Months Ended March 31,
	2019		2018		2019		2018		2020		2019
Lease and Well	$	13.3	$	12.9	$	40.6	$	37.1	$	15.1	$	13.7
Gathering and Processing Costs	0.3		0.1		0.8		0.3		0.3		0.2
Exploration Costs	5.2		5.8		18.1		18.4		7.2		6.5
General and Administrative	35.9		30.2		72.8		60.5		17.5		18.7
Total	$	54.7	$	49.0	$	132.3	$	116.3	$	40.1	$	39.1

The Amended and Restated EOG Resources, Inc. 2008 Omnibus Equity Compensation Plan (2008 Plan) provides for grants of stock options, stock-settled stock appreciation rights (SARs), restricted stock and restricted stock units, performance units and other stock-based awards.

~~EOG RESOURCES, INC.~~

~~NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – (Continued)~~

~~(Unaudited)~~

At ~~September 30, 2019,~~March 31, 2020, approximately ~~7.7~~6.7 million common shares remained available for grant under the 2008 Plan. EOG's policy is to issue shares related to 2008 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 ~~$20.4~~$14.1 million and ~~$21.7~~$13.9 million during the three months ended ~~September 30,~~March 31, 2020 and 2019, ~~and 2018, respectively, and $47.8 million and $45.4 million during the nine months ended September 30, 2019 and 2018,~~ respectively.

Weighted average fair values and valuation assumptions used to value stock option, SAR and ESPP grants during the ~~nine-month~~three-month periods ended ~~September 30,~~March 31, 2020 and 2019 ~~and 2018~~ are as follows:


	Stock Options/SARs						ESPP						Stock Options/SARs						ESPP
	Nine Months Ended September 30,						Nine Months Ended September 30,						Three Months Ended March 31,						Three Months Ended March 31,
	2019			2018			2019			2018			2020			2019			2020			2019
Weighted Average Fair Value of Grants	$	19.49		$	33.49		$	22.83		$	25.52		$	19.67		$	27.19		$	20.80		$	22.98
Expected Volatility	32.01		%	28.22		%	34.83		%	24.36		%	33.43		%	31.81		%	35.24		%	36.31		%
Risk-Free Interest Rate	1.69		%	2.68		%	2.28		%	1.86		%	1.43		%	2.51		%	1.56		%	2.48		%
Dividend Yield	1.39		%	0.72		%	1.04		%	0.64		%	1.60		%	0.88		%	1.56		%	0.83		%
Expected Life	5.1 years			5.0 years			0.5 years			0.5 years			5.0 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.

EOG RESOURCES, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

(Unaudited)

The following table sets forth stock option and SAR transactions for the ~~nine-month~~three-month periods ended ~~September 30,~~March 31, 2020 and 2019 ~~and 2018~~ (stock options and SARs in thousands):


	Nine Months Ended September 30, 2019				Nine Months Ended September 30, 2018				Three Months Ended March 31, 2020				Three Months Ended March 31, 2019
	Number of Stock Options/SARs		Weighted Average Grant Price		Number of Stock Options/SARs		Weighted Average Grant Price		Number of Stock Options/SARs		Weighted Average Grant Price		Number of Stock Options/SARs		Weighted Average Grant Price
Outstanding at January 1	8,310		$	96.90	9,103		$	83.89	9,395		$	94.53	8,310		$	96.90
Granted	1,946		75.43		1,884		126.65		9		75.44		17		96.67
Exercised ⁽¹⁾	(586	)	61.19		(2,144	)	69.62		(23	)	69.59		(43	)	69.94
Forfeited	(200	)	104.89		(167	)	91.89		(47	)	96.81		(48	)	105.43
Outstanding at September 30 ⁽²⁾	9,470		$	94.53	8,676		$	96.55
Outstanding at March 31 ⁽²⁾									9,334		$	94.56	8,236		$	96.99
Vested or Expected to Vest ⁽³⁾	9,127		$	94.51	8,316		$	96.08	8,998		$	94.55	7,892		$	96.53
Exercisable at September 30 ⁽⁴⁾	5,307		$	94.08	4,202		$	85.80
Exercisable at March 31 ⁽⁴⁾									5,249		$	94.33	3,997		$	86.25


(1)	The total intrinsic value of stock options/SARs exercised during the ~~nine~~three months ended ~~September 30,~~March 31, 2020 and 2019 was $0.4 millionand ~~2018 was $13.3 million and $103.7~~$1.1 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 ~~September 30,~~March 31, 2020 and 2019 was 0 and ~~2018 was $4.8 million and $269.1~~$51.8 million, respectively. At ~~September 30,~~March 31, 2020 and 2019, ~~and 2018,~~ the weighted average remaining contractual life was ~~4.5~~4.0 years and ~~4.8~~4.2 years, respectively.


(3)	The total intrinsic value of stock options/SARs vested or expected to vest at ~~September 30,~~March 31, 2020 and 2019 was 0 and ~~2018 was $4.8 million and $261.9~~$51.1 million, respectively. At ~~September 30,~~March 31, 2020 and 2019, ~~and 2018,~~ the weighted average remaining contractual life was ~~4.5~~4.0 years and ~~4.7~~4.1 years, respectively.


(4)	The total intrinsic value of stock options/SARs exercisable at ~~September 30,~~March 31, 2020 and 2019 was 0 and ~~2018 was $4.7 million and $175.5~~$43.1 million, respectively. At ~~September 30,~~March 31, 2020 and 2019, ~~and 2018,~~ the weighted average remaining contractual life was ~~3.3~~2.8 years and ~~3.4~~2.7 years, respectively.

~~EOG RESOURCES, INC.~~

~~NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – (Continued)~~

~~(Unaudited)~~

At ~~September 30, 2019,~~March 31, 2020, unrecognized compensation expense related to non-vested stock option, SAR and ESPP grants totaled ~~$100.5~~$74.9 million. Such unrecognized expense will be amortized on a straight-line basis over a weighted average period of ~~2.2~~1.7 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 ~~$24.7~~$24.8 million and ~~$17.5~~$23.3 million for the three months ended ~~September 30,~~March 31, 2020 and 2019, ~~and 2018, respectively, and $71.1 million and $58.8 million for the nine months ended September 30, 2019 and 2018,~~ respectively.

The following table sets forth restricted stock and restricted stock unit transactions for the ~~nine-month~~three-month periods ended ~~September 30,~~March 31, 2020 and 2019 ~~and 2018~~ (shares and units in thousands):


	Nine Months Ended September 30, 2019				Nine Months Ended September 30, 2018				Three Months Ended March 31, 2020				Three Months Ended March 31, 2019
	Number of Shares and Units		Weighted Average Grant Date Fair Value		Number of Shares and Units		Weighted Average Grant Date Fair Value		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	3,792		$	96.64	3,905		$	88.57	4,546		$	90.16	3,792		$	96.64
Granted	1,728		80.12		792		117.67		26		63.48		371		96.72
Released ⁽¹⁾	(732	)	97.51		(708	)	77.46		(259	)	88.19		(247	)	93.37
Forfeited	(129	)	97.81		(150	)	91.36		(11	)	89.86		(26	)	98.11
Outstanding at September 30 ⁽²⁾	4,659		$	90.34	3,839		$	96.52
Outstanding at March 31 ⁽²⁾									4,302		$	90.12	3,890		$	96.85


(1)	The total intrinsic value of restricted stock and restricted stock units released during the ~~nine~~three months ended ~~September 30,~~March 31, 2020 and 2019 ~~and 2018~~ was ~~$61.2~~$11.0 million and ~~$80.2~~$22.0 million, respectively. The intrinsic value is based upon the closing price of EOG's common stock on the date the restricted stock and restricted stock units are released.


(2)	The total intrinsic value of restricted stock and restricted stock units outstanding at ~~September 30,~~March 31, 2020 and 2019 ~~and 2018~~ was ~~$345.8~~$154.5 million and ~~$489.7~~$370.2 million, respectively.

At ~~September 30, 2019,~~March 31, 2020, unrecognized compensation expense related to restricted stock and restricted stock units totaled ~~$227.5~~$177.8 million. Such unrecognized expense will be amortized on a straight-line basis over a weighted average period of ~~2.0~~1.6 years.

EOG RESOURCES, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

(Unaudited)

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 ~~$9.6~~$1.2 million and ~~$9.8~~$1.9 million for the three months ended ~~September 30,~~March 31, 2020 and 2019, ~~and 2018, respectively, and $13.4 million and $12.1 million for the nine months ended September 30, 2019 and 2018,~~ respectively.

~~EOG RESOURCES, INC.~~

~~NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – (Continued)~~

~~(Unaudited)~~

The following table sets forth the performance unit transactions for the ~~nine-month~~three-month periods ended ~~September 30,~~March 31, 2020 and 2019 ~~and 2018~~ (units in thousands):


	Nine Months Ended September 30, 2019					Nine Months Ended September 30, 2018				Three Months Ended March 31, 2020					Three Months Ended March 31, 2019
	Number of Units			Weighted Average Price per Grant Date		Number of Units		Weighted Average Price per Grant Date		Number of Units			Weighted Average Price per Grant Date		Number of Units	Weighted Average Price per Grant Date
Outstanding at January 1	539			$	101.53	502		$	90.96	598			$	92.19	539	$	101.53
Granted	172			75.09		107		127.00		—			—		—	—
Granted for Performance Multiple ⁽¹⁾	72			69.43		72		101.87		66			100.95		72	69.43
Released ⁽²⁾	(185	)		94.63		(148	)	84.43		(121	)		104.69		—	—
Forfeited	—			—		—		—		—			—		—	—
Outstanding at September 30 ⁽³⁾	598		(4)	$	92.19	533		$	101.50
Outstanding at March 31 ⁽³⁾										543		(4)	$	90.48	611	$	97.75


(1)	Upon completion of the Performance Period for the performance units granted in ~~2015~~2016 and ~~2014,~~2015, a performance multiple of 150% and 200%, respectively, was applied to each of the grants resulting in additional grants of performance units in February ~~2019~~2020 and February ~~2018,~~2019, respectively.

(2)

The total intrinsic value of performance units released during the ~~nine~~three months ended ~~September 30, 2019~~March 31, 2020 ~~and 2018,~~ was ~~$15.4 million and $17.7 million, respectively.~~$9.0 million. The intrinsic value is based upon the closing price of EOG's common stock on the date the performance units are released. There were 0 performance units released during the three months ended March 31, 2019.


(3)	The total intrinsic value of performance units outstanding at ~~September 30, 2019~~March 31, 2020 and ~~2018~~2019 was approximately ~~$44.4~~$19.5 million and ~~$68.0~~$58.1 million, respectively.


(4)	Upon the application of the relevant performance multiple at the completion of each of the remaining Performance Periods, a minimum of ~~102 thousand~~179 and a maximum of ~~1,094 thousand~~907 performance units could be outstanding.

At ~~September 30, 2019,~~March 31, 2020, unrecognized compensation expense related to performance units totaled ~~$10.1~~$7.5 million. Such unrecognized expense will be amortized on a straight-line basis over a weighted average period of ~~2.2~~2.0 years.

EOG RESOURCES, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

(Unaudited)

3. Net Income Per Share

The following table sets forth the computation of Net Income Per Share for the three-month ~~and nine-month~~ periods ended ~~September 30,~~March 31, 2020 and 2019 ~~and 2018~~ (in thousands, except per share data):


	Three Months Ended September 30,				Nine Months Ended September 30,				Three Months Ended March 31,
	2019		2018		2019		2018		2020		2019
Numerator for Basic and Diluted Earnings Per Share -
Net Income	$	615,122	$	1,190,952	$	2,098,389	$	2,526,272	$	9,813	$	635,426
Denominator for Basic Earnings Per Share -
Weighted Average Shares	577,839		577,254		577,498		576,431		578,462		577,207
Potential Dilutive Common Shares -
Stock Options/SARs	203		1,432		371		1,317
Stock Options/SARs/ESPP									24		472
Restricted Stock/Units and Performance Units	3,229		2,873		3,321		2,694		1,797		2,543
Denominator for Diluted Earnings Per Share -
Adjusted Diluted Weighted Average Shares	581,271		581,559		581,190		580,442		580,283		580,222
Net Income Per Share
Basic	$	1.06	$	2.06	$	3.63	$	4.38	$	0.02	$	1.10
Diluted	$	1.06	$	2.05	$	3.61	$	4.35	$	0.02	$	1.10

The diluted earnings per share calculation excludes stock options, SARs and ~~SARs~~ESPP that were anti-dilutive. Shares underlying the excluded stock options, SARs and ~~SARs~~ESPP were ~~6.8~~9.4 million and ~~0.5~~4.9 million shares for the three months ended ~~September 30,~~March 31, 2020 and 2019, ~~and 2018, respectively, and were 6.2 million and 0.2 million shares for the nine months ended September 30, 2019 and 2018,~~ respectively.

~~EOG RESOURCES, INC.~~

~~NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – (Continued)~~

~~(Unaudited)~~

4. Supplemental Cash Flow Information

Net cash paid (received) for interest and income taxes was as follows for the ~~nine-month~~three-month periods ended ~~September 30,~~March 31, 2020 and 2019 ~~and 2018~~ (in thousands):


	Nine Months Ended September 30,					Three Months Ended March 31,
	2019			2018		2020		2019
Interest ⁽¹⁾	$	154,852		$	172,076	$	46,897	$	47,771
Income Taxes, Net of Refunds Received	$	(314,689	)	$	81,059	$	15,066	$	(9,307	)


(1)	Net of capitalized interest of ~~$28~~$9 million and ~~$18~~$7 million for the ~~nine~~three months ended ~~September 30,~~March 31, 2020 and 2019, ~~and 2018,~~ respectively.

EOG's accrued capital expenditures at ~~September 30,~~March 31, 2020 and 2019 ~~and 2018~~ were ~~$568~~$642 million and ~~$702~~$706 million, respectively.

Non-cash investing activities for the ~~nine~~three months ended ~~September 30,~~March 31, 2020 and 2019, ~~and 2018,~~ included additions of ~~$85~~$29 million and ~~$222~~$62 million, respectively, to EOG's oil and gas properties as a result of property exchanges. Non-cash investing activities for the ~~nine~~three months ended ~~September 30, 2018~~March 31, 2020 included additions of $49 million to EOG's other property, plant and equipment primarily in connection with a finance lease ~~transaction in the Permian Basin.~~

~~Cash paid for leases for the nine months ended September 30, 2019, is disclosed in Note 14.~~transaction.

EOG RESOURCES, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

(Unaudited)

5. Segment Information

Selected financial information by reportable segment is presented below for the three-month ~~and nine-month~~ periods ended ~~September 30,~~March 31, 2020 and 2019 ~~and 2018~~ (in thousands):


	Three Months Ended September 30,						Nine Months Ended September 30,						Three Months Ended March 31,
	2019			2018			2019			2018			2020			2019
Operating Revenues and Other
United States	$	4,224,510		$	4,653,342		$	12,813,318		$	12,339,086		$	4,660,735		$	3,977,019
Trinidad	64,726			84,648			205,726			247,272			41,643			69,868
Other International ⁽¹⁾	14,219			43,634			40,683			114,505			15,314			11,755
Total	$	4,303,455		$	4,781,624		$	13,059,727		$	12,700,863		$	4,717,692		$	4,058,642
Operating Income (Loss)
United States	$	825,983		$	1,458,641		$	2,784,793		$	3,251,377		$	105,406		$	850,900
Trinidad	8,991			48,988			82,213			117,106			12,663			38,832
Other International ⁽¹⁾	(7,015		)	(942		)	(31,746		)	(22,277		)
Other International ^{(1) (2)}													(60,484		)	(13,202		)
Total	827,959			1,506,687			2,835,260			3,346,206			57,585			876,530
Reconciling Items
Other Income (Expense), Net	9,118			3,308			23,233			(4,516		)
Other Income, Net													18,108			5,612
Interest Expense, Net	(39,620		)	(63,632		)	(144,434		)	(189,032		)	(44,690		)	(54,906		)
Income Before Income Taxes	$	797,457		$	1,446,363		$	2,714,059		$	3,152,658		$	31,003		$	827,236


(1)	Other International primarily consists of EOG's ~~United Kingdom,~~ China and Canada operations. ~~The United Kingdom operations were sold in~~


(2)	In the ~~fourth~~first quarter of ~~2018.~~2020, EOG recorded pretax impairment charges of $60 million for firm commitment contracts related to its decision to exit the Horn River Basin in British Columbia, Canada.

~~EOG RESOURCES, INC.~~

~~NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – (Continued)~~

~~(Unaudited)~~

Total assets by reportable segment are presented below at ~~September 30, 2019~~March 31, 2020 and December 31, ~~2018~~2019 (in thousands):


	At September 30, 2019		At December 31, 2018		At March 31, 2020		At December 31, 2019
Total Assets
United States	$	35,765,137	$	33,178,733	$	36,921,668	$	36,274,942
Trinidad	617,465		629,633		538,159		705,747
Other International ⁽¹⁾	159,667		126,108		174,257		143,919
Total	$	36,542,269	$	33,934,474	$	37,634,084	$	37,124,608


(1)	Other International primarily consists of EOG's China and Canada operations.

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 ~~nine-month~~three-month periods ended ~~September 30,~~March 31, 2020 and 2019 ~~and 2018~~ (in thousands):


	Nine Months Ended September 30,						Three Months Ended March 31,
	2019			2018			2020			2019
Carrying Amount at January 1	$	954,377		$	946,848		$	1,110,710		$	954,377
Liabilities Incurred	78,025			63,443			15,573			15,360
Liabilities Settled ⁽¹⁾	(52,443		)	(15,319		)	(24,430		)	(24,709		)
Accretion	31,890			27,306			11,404			10,193
Revisions	71,145			(39,137		)	(64		)	(9,704		)
Foreign Currency Translations	154			(2,197		)	(388		)	112
Carrying Amount at September 30	$	1,083,148		$	980,944
Carrying Amount at March 31							$	1,112,805		$	945,629

Current Portion	$	27,055		$	18,209		$	37,641		$	26,182
Noncurrent Portion	$	1,056,093		$	962,735		$	1,075,164		$	919,447


(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 ~~nine-month~~three-month period ended ~~September 30, 2019,~~March 31, 2020, are presented below (in thousands):


	Nine Months Ended September 30, 2019			Three Months Ended March 31, 2020
Balance at January 1	$	4,121		$	25,897
Additions Pending the Determination of Proved Reserves	48,917			25,068
Reclassifications to Proved Properties	(6,286		)	(2,178		)
Costs Charged to Expense(1)	(22,421		)	(4,474		)
Balance at September 30	$	24,331
Balance at March 31				$	44,313

~~EOG RESOURCES, INC.~~

~~NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – (Continued)~~

~~(Unaudited)~~


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

At ~~September 30, 2019,~~March 31, 2020, all capitalized exploratory well costs had been capitalized for periods of less than one year.

8. Commitments and Contingencies

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

EOG RESOURCES, INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

(Unaudited)

9. �� Pension and Postretirement Benefits

EOG has defined contribution pension plans in place for most of its employees in the United States, and a defined benefit pension plan covering certain of its employees in Trinidad. For the ~~nine~~three months ended ~~September 30,~~March 31, 2020 and 2019, ~~and 2018,~~ EOG's total costs recognized for these pension plans were ~~$34~~$9.5 million and ~~$30~~$12.0 million, respectively. EOG also has postretirement medical and dental plans in place for eligible employees and their dependents in the United States and Trinidad, the costs of which are not material.

10. Long-Term Debt and Common Stock

Long-Term Debt. EOG had 0 outstanding commercial paper borrowings at ~~September 30, 2019~~March 31, 2020 and December 31, ~~2018~~2019, and did not utilize any such borrowings during the nine months ended September 30, 2019. During the nine months ended September 30, 2018, EOG utilized commercial paper borrowings, bearing market interest rates, for various corporate financing purposes. The average borrowings outstanding under the commercial paper program were $11 million during the nine months ended September 30, 2018. The weighted average interest rate for commercial paper borrowings during the ~~nine~~three months ended ~~September 30, 2018, was 1.97%.~~March 31, 2020 and 2019.

~~On June 3, 2019, EOG repaid upon maturity the $900~~At March 31, 2020, $500 million aggregate principal amount of ~~its 5.625%~~EOG's 4.40% Senior Notes due ~~2019.~~2020 and $750 million aggregate principal amount of EOG's 4.10% Senior Notes due 2021 were reclassified as long-term debt as a result of EOG's intent and ability to ultimately replace such amounts with other long-term debt.

~~On June 27, 2019,~~ EOG ~~entered into~~currently has a ~~new~~ $2.0 billion senior unsecured Revolving Credit Agreement ~~(New Facility)~~(Agreement) with domestic and foreign lenders (Banks). The ~~New Facility replaced EOG’s $2.0 billion senior unsecured Revolving Credit~~ Agreement ~~dated as of July 21, 2015, with domestic and foreign lenders (2015 Facility), which had a scheduled maturity date of~~ ~~July 21, 2020~~ ~~and which was terminated by EOG (without penalty), effective as of June 27, 2019, in connection with the completion of the New Facility.~~

~~The New Facility~~ 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 ~~New Facility~~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 ~~New Facility~~Agreement will accrue interest based, at ~~EOG’s~~EOG's option, on either ~~the London InterBank Offered Rate~~LIBOR plus an applicable margin (Eurodollar ~~Rate)~~rate) or the ~~Base Rate~~base rate (as defined in the ~~New Facility)~~Agreement) plus an applicable margin. The ~~applicable margin used in connection with interest rates and fees will be based on EOG’s credit rating for its senior unsecured long-term debt at the applicable time.~~

~~Consistent with the terms of the 2015 Facility, the New Facility~~Agreement contains representations, warranties, covenants and events of default that ~~we believe~~EOG believes are customary for ~~investment grade,~~investment-grade, senior unsecured commercial bank credit agreements, including a financial covenant for the maintenance of a ratio of total debt-to-total capitalization (as such terms are defined in the ~~New Facility)~~Agreement) of no greater than 65%. At ~~September 30, 2019,~~March 31, 2020, EOG was in compliance with this financial covenant.

~~There~~ At March 31, 2020 and December 31, 2019, there were 0no borrowings or letters of credit outstanding under the 2015 Facility as of (i) December 31, 2018 or (ii) the June 27, 2019 effective date of the closing of the New Facility and termination of the 2015 Facility. Further, at September 30, 2019, there were 0 borrowings or letters of credit outstanding under the New Facility.Agreement. The Eurodollar ~~Rate~~rate and ~~Base Rate~~base rate (inclusive of the applicable margin), had there been any amounts borrowed under the ~~New Facility~~Agreement at ~~September 30, 2019,~~March 31, 2020, would have been ~~2.92%~~1.89% and ~~5.0%~~3.25%, respectively.

On April 1, 2020, EOG ~~RESOURCES, INC.~~

~~NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)~~

~~(Unaudited)~~repaid upon maturity the $500 million aggregate principal amount of its 2.45% Senior Notes due 2020.

On April 14, 2020, EOG closed on its offering of $750 million aggregate principal amount of its 4.375% Senior Notes due 2030 and $750 million aggregate principal amount of its 4.950% Senior Notes due 2050 (together, the Notes). Interest on the Notes is payable semi-annually in arrears on April 15 and October 15 of each year, beginning on October 15, 2020. EOG received net proceeds of approximately $1.48 billion from the issuance of the Notes, which will be used for general corporate purposes, including the funding of future capital expenditures and the repayment of the 4.40% Senior Notes due 2020 when they mature on June 1, 2020.

Common Stock. On ~~May 2, 2019,~~February 27, 2020, EOG's Board of Directors increased the quarterly cash dividend on the common stock from the previous ~~$0.22~~$0.2875 per share to ~~$0.2875~~$0.375 per share, effective beginning with the dividend paid on ~~July 31, 2019,~~April 30, 2020, to stockholders of record as of ~~July 17, 2019.~~April 16, 2020.

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 ~~2018~~2019 Annual Report, certain of EOG's financial and nonfinancial assets and liabilities are reported at fair value on the Condensed Consolidated Balance Sheets. The following table provides fair value measurement information within the fair value hierarchy for certain of EOG's financial assets and liabilities carried at fair value on a recurring basis at ~~September 30, 2019~~March 31, 2020 and December 31, ~~2018~~2019 (in thousands):


	Fair Value Measurements Using:								Fair Value Measurements Using:
	Quoted Prices in Active Markets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Total		Quoted Prices in Active Markets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Total
At September 30, 2019
Financial Assets:
Natural Gas Swaps	$	—	$	3,629	$	—	$	3,629
At March 31, 2020
Financial Assets: ⁽¹⁾
Crude Oil Swaps	—		119,088		—		119,088		$	—	$	898,090	$	—	$	898,090
Crude Oil Basis Swaps	—		1,162		—		1,162		—		888		—		888
Natural Gas Basis Swaps	—		230		—		230
Crude Oil Roll Differential Swaps									—		7,255		—		7,255
Natural Gas Liquids Swaps									—		30,822		—		30,822
Natural Gas Collars									—		3,678		—		3,678
Financial Liabilities:
Crude Oil Basis Swaps	$	—	$	1,482	$	—	$	1,482	$	—	$	93	$	—	$	93
Natural Gas Basis Swaps	—		21		—		21		—		7,712		—		7,712

At December 31, 2018
Financial Assets:
Crude Oil Basis Swaps	$	—	$	23,806	$	—	$	23,806
At December 31, 2019
Financial Assets: ⁽¹⁾
Natural Gas Liquids Swaps									$	—	$	3,401	$	—	$	3,401
Natural Gas Basis Swaps									—		970		—		970
Financial Liabilities: ⁽²⁾
Crude Oil Swaps									$	—	$	23,266	$	—	$	23,266


(1)	$933 million and $1 million are included in "Current Assets - Assets from Price Risk Management Activities" at March 31, 2020 and December 31, 2019, respectively, on the Condensed Consolidated Balance Sheets.


(2)	$20 million is included in "Current Liabilities - Liabilities from Price Risk Management Activities" at December 31, 2019, on the Condensed Consolidated Balance Sheets.

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.

~~Proved~~During the three months ended March 31, 2020, due to the decline in commodity prices, proved oil and gas properties, leasehold costs and other assets with a carrying amount of ~~$472~~$1,813 million were written down to their fair value of ~~$340~~$357 million, resulting in pretax impairment charges of ~~$132~~$1,456 million for the ~~nine~~three months ended ~~September 30, 2019. Included in the $132 million pretax impairment charges are $89 million for a commodity price-related write-down of other assets.~~March 31, 2020.

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.

EOG RESOURCES, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

(Unaudited)

Fair Value ~~of Debt.~~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 ~~September 30, 2019~~March 31, 2020 and December 31, ~~2018, respectively,~~2019, EOG had outstanding $5,140 ~~million and $6,040~~ million aggregate principal amount of senior notes, which had estimated fair values at such dates of approximately ~~$5,453~~$5,145 million and ~~$6,027~~$5,452 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.

~~EOG RESOURCES, INC.~~

~~NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – (Continued)~~

~~(Unaudited)~~

12. Risk Management Activities

Commodity Price Risk. As more fully discussed in Note 12 to the Consolidated Financial Statements included in EOG's ~~2018~~2019 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~~Crude Oil Derivative Contracts. Prices received by EOG for its crude oil production generally vary from U.S. New York Mercantile Exchange (NYMEX) West Texas Intermediate (WTI) prices due to adjustments for delivery location (basis) and other factors. EOG has entered into crude oil basis swap contracts in order to fix the differential between Intercontinental Exchange (ICE) Brent pricing and pricing in ~~Midland, Texas, and~~ Cushing, Oklahoma ~~(Midland~~(ICE Brent Differential). Presented below is a comprehensive summary of EOG's ~~Midland~~ICE Brent Differential basis swap contracts ~~for the nine months ended September 30, 2019.~~as of March 31, 2020. The weighted average price differential expressed in dollars per barrel ($/Bbl) represents the amount of ~~reduction~~addition to Cushing, Oklahoma, prices for the notional volumes expressed in barrels per day (Bbld) covered by the basis swap contracts.

Midland Differential Basis Swap Contracts
Volume (Bbld)
Weighted Average Price Differential
($/Bbl)

2019
January 1, 2019 through October 31, 2019 (closed) 20,000
$ 1.075
November 1, 2019 through December 31, 2019 20,000
1.075



ICE Brent Differential Basis Swap Contracts
	Volume (Bbld)	Weighted Average Price Differential ($/Bbl)


2020
May 2020	10,000	$	4.92

EOG has also entered into crude oil basis swap contracts in order to fix the differential between pricing in ~~the U.S. Gulf Coast~~Houston, Texas, and Cushing, Oklahoma ~~(Gulf Coast~~(Houston Differential). Presented below is a comprehensive summary of EOG's ~~Gulf Coast~~Houston Differential basis swap contracts ~~for the nine months ended September 30, 2019.~~as of March 31, 2020. The weighted average price differential expressed in $/Bbl represents the amount of addition to Cushing, Oklahoma, prices for the notional volumes expressed in Bbld covered by the basis swap contracts.

Gulf Coast Differential Basis Swap Contracts
Volume (Bbld)
Weighted Average Price Differential
($/Bbl)

2019
January 1, 2019 through October 31, 2019 (closed) 13,000
$ 5.572
November 1, 2019 through December 31, 2019 13,000
5.572



Houston Differential Basis Swap Contracts
	Volume (Bbld)	Weighted Average Price Differential ($/Bbl)


2020
May 2020	10,000	$	1.55

~~Presented below is a comprehensive summary of EOG's crude oil price swap contracts for the nine months ended September 30, 2019, with notional volumes expressed in Bbld and prices expressed in $/Bbl.~~

Crude Oil Price Swap Contracts
Volume (Bbld) Weighted Average Price ($/Bbl)
2019
April 2019 (closed) 25,000
$ 60.00
May 1, 2019 through September 30, 2019 (closed) 150,000
62.50
October 1, 2019 through December 31, 2019 150,000
62.50

EOG RESOURCES, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

(Unaudited)

EOG has also entered into crude oil swaps to fix the differential in pricing between the NYMEX calendar month average and the physical crude oil delivery month (Roll Differential). Presented below is a comprehensive summary of EOG's Roll Differential swap contracts as of March 31, 2020. The weighted average price differential expressed in $/Bbl represents the amount of net addition (reduction) to delivery month prices for the notional volumes expressed in Bbld covered by the swap contracts.



Roll Differential Swap Contracts
	Volume (Bbld)	Weighted Average Price Differential ($/Bbl)


2020
February 1, 2020 through April 30, 2020 (closed)	10,000	$	0.70
May 1, 2020 through December 31, 2020	10,000	0.70

Presented below is a comprehensive summary of EOG's crude oil NYMEX WTI price swap contracts as of March 31, 2020, with notional volumes expressed in Bbld and prices expressed in $/Bbl.



Crude Oil NYMEX WTI Price Swap Contracts
	Volume (Bbld)	Weighted Average Price ($/Bbl)


2020
January 1, 2020 through March 31, 2020 (closed)	200,000	$	59.33
April 1, 2020 through June 30, 2020	265,000	51.36
July 2020	207,000	44.94
August 1, 2020 through September 30, 2020	107,000	58.94

NGLs Derivative Contracts. Presented below is a comprehensive summary of EOG's Mont Belvieu propane (non-TET) financial price swap contracts (Mont Belvieu Propane Price Swap Contracts) as of March 31, 2020, with notional volumes expressed in Bbld and prices expressed in $/Bbl.



Mont Belvieu Propane Price Swap Contracts
	Volume (Bbld)	Weighted Average Price ($/Bbl)


2020
January 1, 2020 through February 29, 2020 (closed)	4,000	$	21.34
March 2020 (closed)	25,000	17.92
April 1, 2020 through December 31, 2020	25,000	17.92

EOG RESOURCES, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

(Unaudited)

Natural Gas Derivative Contracts. EOG has entered into natural gas collar contracts, which establish ceiling and floor prices for the sale of notional volumes of natural gas as specified in the collar contracts. The collars require that EOG pay the difference between the ceiling price and the NYMEX Henry Hub natural gas price for the contract month (Henry Hub Index Price) in the event the Henry Hub Index Price is above the ceiling price. The collars grant EOG the right to receive the difference between the floor price and the Henry Hub Index Price in the event the Henry Hub Index Price is below the floor price. On March 24, 2020, EOG executed the early termination provision granting EOG the right to terminate certain 2020 natural gas collar contracts with notional volumes of 250,000 million British thermal units (MMBtu) per day (MMBtud) at a weighted average ceiling price of $2.50 per MMBtu and a weighted average floor price of $2.00 per MMBtu for the period April 1, 2020 through July 31, 2020. The net cash EOG received for settling these contracts was $7.8 million. Presented below is a comprehensive summary of EOG's natural gas collar contracts as of March 31, 2020, with notional volumes expressed in MMBtud and prices expressed in dollars per MMBtu ($/MMBtu).



Natural Gas Collar Contracts
		Weighted Average Price ($/MMBtu)
	Volume (MMBtud)	Ceiling Price		Floor Price


2020
April 1, 2020 through July 31, 2020 (closed)	250,000	$	2.50	$	2.00
August 1, 2020 through October 31, 2020	250,000	2.50		2.00

Prices received by EOG for its natural gas production generally vary from NYMEX Henry Hub prices due to adjustments for delivery location (basis) and other factors. EOG has entered into natural gas basis swap contracts in order to fix the differential between pricing in the Rocky Mountain area and NYMEX Henry Hub prices (Rockies Differential). Presented below is a comprehensive summary of EOG's Rockies Differential basis swap contracts ~~for the nine months ended September 30, 2019.~~as of March 31, 2020. The weighted average price differential expressed in ~~dollars per million British thermal units ($/MMBtu)~~$/MMBtu represents the amount of reduction to NYMEX Henry Hub prices for the notional volumes expressed in ~~MMBtu per day (MMBtud)~~MMBtud covered by the basis swap contracts.

Rockies Differential Basis Swap Contracts
Volume (MMBtud)
Weighted Average Price Differential
($/MMBtu)

2020
January 1, 2020 through December 31, 2020 14,000
$ 0.55



Rockies Differential Basis Swap Contracts
	Volume (MMBtud)	Weighted Average Price Differential ($/MMBtu)


2020
January 1, 2020 through March 31 2020 (closed)	30,000	$	0.55
April 1, 2020 through December 31, 2020	30,000	0.55

EOG has also entered into natural gas basis swap contracts in order to fix the differential between pricing at the Houston Ship Channel (HSC) and NYMEX Henry Hub prices (HSC Differential). On March 27, 2020, EOG executed the early termination provision granting EOG the right to terminate certain 2020 HSC Differential basis swaps with notional volumes of 60,000 MMBtud at a weighted average price differential of $0.05 per MMBtu for the period April 1, 2020 through December 31, 2020. The net cash EOG paid for settling these contracts was $0.4 million. Presented below is a comprehensive summary of EOG's ~~natural gas price~~HSC Differential basis swap contracts as of March 31, 2020. The weighted average price differential expressed in $/MMBtu represents the amount of reduction to NYMEX Henry Hub prices for the ~~nine months ended September 30, 2019, with~~ notional volumes expressed in MMBtud ~~and prices expressed in $/MMBtu.~~covered by the basis swap contracts.

Natural Gas Price Swap Contracts
Volume (MMBtud) Weighted Average Price ($/MMBtu)
2019
April 1, 2019 through October 31, 2019 (closed) 250,000
$ 2.90



HSC Differential Basis Swap Contracts
	Volume (MMBtud)	Weighted Average Price Differential ($/MMBtu)


2020
January 1, 2020 through December 31, 2020 (closed)	60,000	$	0.05

EOG RESOURCES, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

(Unaudited)

EOG has also entered into natural gas basis swap contracts in order to fix the differential between pricing at the Waha Hub in West Texas and NYMEX Henry Hub prices (Waha Differential). Presented below is a comprehensive summary of EOG's Waha Differential basis swap contracts as of March 31, 2020. The weighted average price differential expressed in $/MMBtu represents the amount of reduction to NYMEX Henry Hub prices for the notional volumes expressed in MMBtud covered by the basis swap contracts.



Waha Differential Basis Swap Contracts
	Volume (MMBtud)	Weighted Average Price Differential ($/MMBtu)


2020
January 1, 2020 through March 31, 2020 (closed)	50,000	$	1.40
April 1, 2020 through December 31, 2020	50,000	1.40

Commodity Derivatives Location on Balance Sheet.The following table sets forth the amounts and classification of EOG's outstanding financial derivative instruments at ~~September 30, 2019~~March 31, 2020 and December 31, ~~2018.~~2019. 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 thousands):


		Fair Value at					Fair Value at
Description	Location on Balance Sheet	September 30, 2019		December 31, 2018		Location on Balance Sheet	March 31, 2020		December 31, 2019
Asset Derivatives
Crude oil and natural gas derivative contracts -
Crude oil, NGLs and natural gas derivative contracts -
Current portion	Assets from Price Risk Management Activities ⁽¹⁾	$	122,627	$	23,806	Assets from Price Risk Management Activities ⁽¹⁾	$	932,928	$	1,299
Liability Derivatives
Crude oil and natural gas derivative contracts -
Noncurrent portion	Other Liabilities	$	21	$	—
Crude oil, NGLs and natural gas derivative contracts -
Current portion						Liabilities from Price Risk Management Activities ⁽²⁾	$	—	$	20,194


(1)	The current portion of Assets from Price Risk Management Activities consists of gross assets of ~~$124~~$941 million, partially offset by gross liabilities of $1$8 million at ~~September 30,~~March 31, 2020. The current portion of Assets from Price Risk Management Activities consists of gross assets of $3 million, partially offset by gross liabilities of $2 million, at December 31, 2019.


(2)	The current portion of Liabilities from Price Risk Management Activities consists of gross liabilities of $23 million, partially offset by gross assets of $3 million, at December 31, 2019.

~~EOG RESOURCES, INC.~~

~~NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – (Continued)~~

~~(Unaudited)~~

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 exposure to significant counterparties on an ongoing basis, including that 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 asset position at ~~September 30, 2019~~March 31, 2020 and December 31, ~~2018.~~2019. EOG had 0 collateral posted orand held collateral of $762 million at ~~September 30, 2019, or~~March 31, 2020, and had 0 collateral posted and held 0 collateral at December 31, ~~2018.~~2019.

~~13. Acquisitions and Divestitures~~

During the nine months ended September 30, 2019, EOG paid cash for property acquisitions of $311 million in the United States. Additionally, during the nine months ended September 30, 2019, EOG recognized net gains on asset dispositions of $4 million and received proceeds of approximately $35 million. During the nine months ended September 30, 2018, EOG recognized net gains on asset dispositions of $95 million, primarily due to non-cash exchanges of unproved leasehold in Texas, New Mexico and Wyoming and received proceeds of approximately $12 million.

~~14. Leases~~

In the ordinary course of business, EOG enters into contracts for drilling, fracturing, compression, real estate and other services which contain equipment and other assets and that meet the definition of a lease under ASU 2016-02. The lease term for these contracts, which includes any renewals at EOG's option that are reasonably certain to be exercised, ranges from one month to 30 years. ROU assets and related liabilities are recognized on commencement date on the Condensed Consolidated Balance Sheets based on future lease payments, discounted based on the rate implicit in the contract, if readily determinable, or EOG's incremental borrowing rate commensurate with the lease term of the contract. EOG estimates its incremental borrowing rate based on the approximate rate required to borrow on a collateralized basis. Contracts with lease terms of less than 12 months are not recorded on the Condensed Consolidated Balance Sheets, but instead are disclosed as short-term lease cost.

EOG has elected not to separate non-lease components from all leases, excluding those for fracturing services, real estate and salt water disposal, as lease payments under these contracts contain significant non-lease components, such as labor and operating costs.

Lease costs are classified by the function of the ROU asset. The lease costs related to exploration and development activities are initially included in the Oil and Gas Properties line on the Condensed Consolidated Balance Sheets and subsequently accounted for in accordance with the Extractive Industries - Oil and Gas Topic of the Accounting Standards Codification. Variable lease cost represents costs incurred above the contractual minimum payments for operating and finance leases. The components of lease cost for the three month and nine month periods ended September 30, 2019, were as follows (in millions):

Three Months Ended September 30, 2019 Nine Months Ended September 30, 2019
Operating Lease Cost $ 138
$ 391
Finance Lease Cost:
Amortization of Lease Assets 3
10
Interest on Lease Liabilities —
1
Variable Lease Cost 39
167
Short-Term Lease Cost 67
295
Total Lease Cost $ 247
$ 864

EOG RESOURCES, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

(Unaudited)

~~The following table sets forth the amounts~~13. Acquisitions and ~~classification of EOG's outstanding ROU assets and related lease liabilities and supplemental information at September 30, 2019 (in millions, except lease terms and discount rates):~~

Description Location on Balance Sheet Amount
Assets
Operating Leases Other Assets $ 842
Finance Leases
Property, Plant and Equipment, Net ⁽¹⁾
56
Total $ 898

Liabilities
Current
Operating Leases Current Portion of Operating Lease Liabilities $ 384
Finance Leases Current Portion of Long-Term Debt 15
Long-Term
Operating Leases Other Liabilities 485
Finance Leases Long-Term Debt 46
Total $ 930


~~(1)~~	~~Finance lease assets are recorded net of accumulated amortization of $57 million at September 30, 2019.~~

Divestitures



	~~Nine Months Ended September 30, 2019~~
~~Weighted Average Remaining Lease Term (in years):~~
~~Operating Leases~~	~~3.2~~
~~Finance Leases~~	~~4.9~~

~~Weighted Average Discount Rate:~~
~~Operating Leases~~	~~3.5~~	%
~~Finance Leases~~	~~3.0~~	%

~~Cash paid for leases was as follows for~~During the ~~nine~~three months ended ~~September 30,~~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. During the three months ended March 31, 2019, ~~(in millions):~~

Nine Months Ended September 30, 2019
Repayment of Operating Lease Liabilities Associated with Operating Activities $ 162
Repayment of Operating Lease Liabilities Associated with Investing Activities 225
Repayment of Finance Lease Liabilities 10

~~Upon adoption~~EOG paid cash for property acquisitions of ~~ASU 2016-02 effective January 1,~~$303 million in the United States. Additionally, during the three months ended March 31, 2019, EOG recognized ~~operating lease ROU assets~~a net loss on asset dispositions of ~~$566 million. Non-cash leasing activities for the nine months ended September 30, 2019, included the addition of $703~~$4 million, ~~of operating leases.~~

~~EOG RESOURCES, INC.~~

~~NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Concluded)~~

~~(Unaudited)~~

~~At September 30, 2019, the future minimum lease payments under non-cancellable leases were as follows (in millions):~~

Operating Leases Finance Leases
October 1, 2019 to December 31, 2019 $ 116
$ 3
2020 377
15
2021 198
15
2022 118
12
2023 50
8
2024 and Beyond 64
14
Total Lease Payments 923
67
Less: Discount to Present Value 54
6
Total Lease Liabilities 869
61
Less: Current Portion of Lease Liabilities 384
15
Long-Term Lease Liabilities $ 485
$ 46

At September 30, 2019, EOG had additional leases of $675 million, of which $24 million, $446 million and $205 million were expected to commence in the remainder of 2019 and in 2020 and 2021, respectively, with lease terms of one month to 10 years.

~~At December 31, 2018 and prior~~primarily due to the ~~adoption~~sale of ~~ASU 2016-02~~proved property in Texas, and ~~other related ASUs, the future minimum commitments under non-cancellable leases, including non-lease components and excluding contracts with lease terms~~received proceeds of ~~less than 12 months, were as follows (in millions):~~

Operating Leases Finance Leases
2019 $ 380
$ 15
2020 213
15
2021 86
15
2022 39
12
2023 30
8
2024 and Beyond 62
14
Total Lease Payments $ 810
$ 79

approximately $15 million.

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. 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 production growth while maintaining 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 that is consistent with efficient, safe and environmentally responsible operations is also an important goal in the implementation of EOG's strategy.

Recent Developments. The recent COVID-19 pandemic and the measures being taken to address and limit the spread of the virus have adversely affected the economies and financial markets of many countries, resulting in an economic downturn that has negatively impacted, and may continue to negatively impact, global demand and prices for crude oil and natural gas liquids (NGLs). See PART II, ITEM 1A, "Risk Factors" below, for further discussion.

In early March 2020, due to the failure of members of the Organization of the Petroleum Exporting Countries and Russia to reach an agreement on individual crude oil production limits, Saudi Arabia unilaterally reduced the sales price of its crude oil and announced that it would increase its crude oil production. The combination of these actions and the effects of the COVID-19 pandemic on crude oil demand, resulted in lower commodity prices in the last month of the first quarter of 2020 that are reflected in EOG's first quarter 2020 financial and operating results. In addition, the decline in worldwide crude oil demand resulting from the growing effects of the COVID-19 pandemic and the increase in crude oil supply from Saudi Arabia and Russia have caused these lower commodity prices to continue in the second quarter of 2020.

In response to the current commodity price environment, EOG has updated its 2020 capital and operating plan to reduce activity across its operating areas and decrease its total anticipated 2020 capital expenditures. EOG has also elected to reduce its 2020 crude oil production, including delaying the startup of new wells and shutting-in or otherwise curtailing existing production. As a result, expects its full-year 2020 total crude oil production to be lower than its full-year 2019 total crude oil production. See "2020 Capital and Operating Plan" below for further discussion.

Commodity Prices. As a result of the many uncertainties associated with (i) the world economic environment, (ii) the COVID-19 pandemic and its effect on the economies and financial markets of many countries and (iii) the actions of Saudi Arabia, Russia and other crude oil producing and exporting nations, and the effect of these uncertainties on worldwide supplies of, and demand for, crude oil and condensate, NGLs and natural gas, EOG is unable to predict what changes may occur in crude oil and condensate, NGLs, and natural gas prices in the future. However, prices for crude oil, NGLs and natural gas have historically been volatile, and this volatility is expected to continue.

The market prices of crude oil and condensate, NGLs and natural gas during the remainder of 2020 will impact the amount of cash generated from EOG's operating activities, which will in turn impact EOG's financial position and results of operations. For the first three months of 2020, the average U.S. New York Mercantile Exchange (NYMEX) crude oil and natural gas prices were $46.08 per barrel and $1.98 per million British thermal units (MMBtu), respectively, representing decreases of 16% and 37%, respectively, from the average NYMEX prices for the same period in 2019. 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. For the period April 1 through April 30, 2020, the average NYMEX crude oil price was $16.70 per barrel, a decline of 64% from the average price for the three-month period ended March 31, 2020.

As previously disclosed, EOG utilizes financial commodity derivative instruments from time to time to manage its exposure to fluctuations in commodity prices. See "Capital Resources and Liquidity - Commodity Derivative Transactions" below for further discussion, including a comprehensive summary of EOG's financial commodity derivative instruments through May 5, 2020.

United States. EOG's efforts to identify plays with large reserve potential have proven to be successful. EOG has placed an emphasis on applying its horizontal drilling and completion expertise to unconventional crude oil and liquids-rich reservoirs, 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 liquids-rich natural gas production. ~~EOG has placed an emphasis on applying its horizontal drilling and completion expertise to unconventional crude oil and liquids-rich reservoirs.~~

Crude oil, natural gas liquids (NGLs) and natural gas prices have been volatile, and this volatility is expected to continue. As a result of the many uncertainties associated with the world political environment, worldwide supplies of, and demand for, crude oil and condensate, NGLs and natural gas and the availability of other energy supplies, EOG is unable to predict what changes may occur in crude oil and condensate, NGLs, and natural gas prices in the future. The market prices of crude oil and condensate, NGLs and natural gas in 2019 will continue to impact the amount of cash generated from EOG's operating activities, which will in turn impact EOG's financial position and results of operations. For the first nine months of 2019, the average U.S. New York Mercantile Exchange (NYMEX) crude oil and natural gas prices were $57.06 per barrel and $2.66 per million British thermal units (MMBtu), respectively, representing decreases of 15% and 7%, respectively, from the average NYMEX prices for the same period in 2018. Market prices for NGLs are influenced by crude oil prices and the composition of NGL production, including ethane, propane and butane, among others. Based on its 2019 drilling and completion plans, EOG expects both its 2019 total production and total crude oil production to increase as compared to 2018.

During the first ~~nine~~three months of ~~2019,~~2020, EOG continued to focus on increasing drilling, completion and operating efficiencies gained in prior years. In addition, EOG continued to evaluate certain potential crude oil and liquids-rich 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 NGL production accounted for approximately 77% of EOG's United States production during ~~both~~ the first ~~nine~~three months of ~~2019~~both 2020 and ~~2018, respectively.~~2019. During the first ~~nine~~three months of ~~2019,~~2020, EOG's drilling and completion activities occurred primarily in the Eagle Ford play, Delaware Basin play and Rocky Mountain area. EOG's major producing areas in the United States are in New Mexico, North Dakota, Texas and Wyoming.

Trinidad. In Trinidad, EOG continues to deliver natural gas under existing supply contracts. Several fields in the South East Coast Consortium (SECC) Block, Modified U(a) Block, Block 4(a), 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. In the ~~third~~first quarter of ~~2019,~~2020, EOG drilled ~~two~~one net ~~wells, one~~well, with an additional well in progress as of ~~which was an unsuccessful exploratory well.~~March 31, 2020. During the remainder of ~~2019,~~2020, EOG plans to complete the well it is currently drilling and drill two additional net ~~wells.~~wells in the second half of 2020.

Other International. In the Sichuan Basin, Sichuan Province, China, EOG ~~drilled two wells~~continues to work closely with our partner, PetroChina, under the Production Sharing Contract and other related agreements, to ensure uninterrupted production in order to reach the ~~first nine months of 2019 to complete the drilling program started in 2018. Additionally, EOG completed two drilled uncompleted wells from 2018 in 2019.~~level allowed by pipeline capacity. All natural gas produced from the Baijaochang Field is sold under a long-term contract to PetroChina.

In Canada, EOG maintains approximately 132,000 net acres with 23 net producing wells in the Horn River Basin in Northeast British Columbia. In March 2020, EOG made the decision to begin the process of exiting its Canada operations.

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.

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.

2020 Capital and Operating Plan. EOG has updated its full-year 2020 capital and operating plan as a result of the significant decline and increased volatility of commodity prices. Under its updated 2020 capital and operating plan, EOG's total anticipated 2020 capital expenditures are estimated to range from approximately $3.3 billion to $3.7 billion, including facilities and gathering, processing and other expenditures, and excluding acquisitions and non-cash transactions. The updated 2020 capital and operating plan represents a reduction in total anticipated capital expenditures compared to the original 2020 capital and operating plan and, as a result, EOG expects its full-year 2020 total crude oil production to be lower than its full-year 2019 total crude oil production.

EOG's 2020 capital expenditures will be focused on drilling operations in its high rate-of-return plays as well as targeted infrastructure, exploration and environmental projects that support the long-term value of EOG. EOG remains flexible and will continue to evaluate its 2020 capital and operating plan. To the extent necessary or prudent, EOG will consider further reducing its 2020 capital expenditures and operating expenses and further curtailing production, including shutting-in or otherwise curtailing uneconomic wells and delaying the startup of new wells. EOG will also continue to exercise financial flexibility with a goal toward preserving liquidity while supporting its dividend.

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 ~~September 30, 2019~~March 31, 2020 and ~~24%~~19% at December 31, ~~2018.~~2019. As used in this calculation, total capitalization represents the sum of total current and long-term debt and total stockholders' equity.

At March 31, 2020, EOG maintained a strong financial and liquidity position, including $2.9 billion of cash and cash equivalents and $2.0 billion of availability under its senior unsecured revolving credit facility. EOG's cash and cash equivalents as of March 31, 2020 included $762 million of collateral deposits from counterparties in anticipation of future settlements of financial commodity derivative contracts.

On ~~June 3, 2019,~~April 1, 2020, EOG repaid, ~~upon maturity~~with cash on hand, the ~~$900~~$500 million aggregate principal amount of its ~~5.625%~~2.45% Senior Notes due ~~2019.~~

~~On June 27, 2019,~~2020 that matured on that date. Additionally, on April 14, 2020, EOG entered into a new $2.0 billion senior unsecured Revolving Credit Agreement (New Facility) with domestic and foreign lenders (Banks). The New Facility replaced EOG's $2.0 billion senior unsecured Revolving Credit Agreement, dated asclosed on its offering of July 21, 2015, which had a scheduled maturity date of July 21, 2020. The New Facility 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 New Facility (i) commits the Banks to provide advances up to an$750 million aggregate principal amount of ~~$2.0~~its 4.375% Senior Notes due 2030 and $750 million aggregate principal amount of its 4.950% Senior Notes due 2050 (together, the Notes). EOG received net proceeds of approximately $1.48 billion ~~at any one time outstanding, with an option for EOG to request increases in~~from 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~~issuance of ~~credit subfacility.~~the Notes.

~~Effective January 1, 2019,~~As of April 30, 2020, EOG ~~adopted the provisions~~had $3.6 billion of ~~Accounting Standards Update (ASU) 2016-02, "Leases (Topic 842)" (ASU 2016-02). ASU 2016-02~~cash and ~~other related ASUs resulted~~cash equivalents and $2.0 billion of availability under its senior unsecured revolving credit facility. EOG's cash and cash equivalents as of April 30, 2020 included approximately $890 million of collateral deposits from counterparties in ~~the recognition~~anticipation of ~~right-of-use assets and related lease liabilities representing the obligation to make lease payments for certain lease transactions and the disclosure~~future settlements of additional leasing information. The adoption of ASU 2016-02 and other related ASUs resulted in a significant increase to assets and liabilities related to operating leases on the Condensed Consolidated Balance Sheet at September 30, 2019. Financial results prior to January 1, 2019, are unchanged. See Note 1 "Summary of Significant Accounting Policies" and Note 14 "Leases" to EOG's Condensed Consolidated Financial Statements in this Quarterly Report on Form 10-Q.financial commodity derivative contracts.

~~Total anticipated 2019 capital expenditures are estimated~~EOG expects to ~~range from approximately $6.2 billion to $6.4 billion, excluding acquisitions and non-cash transactions. The majority~~repay at maturity, with cash on hand, the $500 million aggregate principal amount of ~~2019 expenditures will be focused~~its 4.40% Senior Notes due 2020 which mature on ~~United States crude oil drilling activities.~~ June 1, 2020.

EOG believes it has significant flexibility and availability with respect to financing alternatives, including borrowings under its commercial paper program, bank borrowings, borrowings under its ~~$2.0 billion~~ senior unsecured revolving credit facility, ~~described above,~~ joint development agreements and similar agreements and equity and debt offerings.

Results of Operations

The following review of operations for the three months ended March 31, 2020 and ~~nine months ended September 30,~~ 2019 ~~and 2018~~ should be read in conjunction with the Condensed Consolidated Financial Statements of EOG and notes thereto included in this Quarterly Report on Form 10‑Q.

Three Months Ended ~~September 30, 2019~~March 31, 2020 vs. Three Months Ended ~~September 30, 2018~~March 31, 2019

Operating Revenues. During the ~~third~~first quarter of ~~2019~~2020, operating revenues ~~decreased $479~~increased $659 million, or ~~10%~~16%, to ~~$4,303~~$4,718 million from ~~$4,782~~$4,059 million for the same period of ~~2018~~2019. Total wellhead revenues, which are revenues generated from sales of EOG's production of crude oil and condensate, NGLs and natural gas, for the ~~third~~first quarter of ~~2019~~2020 decreased ~~$468~~$318 million, or ~~14%~~12%, to ~~$2,853~~$2,436 million from ~~$3,321~~$2,754 million for the same period of ~~2018~~2019. EOG recognized net gains on the mark-to-market of financial commodity derivative contracts of ~~$86~~$1,206 million for the ~~third~~first quarter of ~~2019~~2020 compared to net losses of ~~$52~~$21 million for the same period of ~~2018~~2019. Gathering, processing and marketing revenues for the ~~third~~first quarter of ~~2019~~2020 decreased ~~$27~~$247 million, or 2%19%, to ~~$1,334~~$1,039 million from ~~$1,361~~$1,286 million for the same period of ~~2018~~2019. Net ~~losses~~gains on asset dispositions were $1$16 million for the ~~third~~first quarter of ~~2019~~2020 compared to net ~~gains~~losses of ~~$116~~$4 million for the same period of ~~2018.~~2019.

Wellhead volume and price statistics for the three-month periods ended ~~September 30,~~March 31, 2020 and 2019 ~~and 2018~~ were as follows:


	Three Months Ended September 30,				Three Months Ended March 31,
	2019		2018		2020		2019
Crude Oil and Condensate Volumes (MBbld) ⁽¹⁾
United States	463.2		409.2		482.7		435.1
Trinidad	0.8		0.8		0.5		0.7
Other International ⁽²⁾	0.1		5.0		0.1		0.1
Total	464.1		415.0		483.3		435.9
Average Crude Oil and Condensate Prices ($/Bbl) ⁽³⁾
United States	$	56.67	$	69.53	$	46.97	$	56.11
Trinidad	48.36		61.71		34.93		43.68
Other International ⁽²⁾	59.87		72.81		57.51		60.13
Composite	56.66		69.55		46.96		56.09
Natural Gas Liquids Volumes (MBbld) ⁽¹⁾
United States	141.3		127.8		161.3		119.8
Other International ⁽²⁾	—		—		—		—
Total	141.3		127.8		161.3		119.8
Average Natural Gas Liquids Prices ($/Bbl) ⁽³⁾
United States	$	12.67	$	30.09	$	10.94	$	20.28
Other International ⁽²⁾	—		—		—		—
Composite	12.67		30.09		10.94		20.28
Natural Gas Volumes (MMcfd) ⁽¹⁾
United States	1,079		948		1,139		1,003
Trinidad	260		260		201		267
Other International ⁽²⁾	34		28		38		38
Total	1,373		1,236		1,378		1,308
Average Natural Gas Prices ($/Mcf) ⁽³⁾
United States	$	1.97	$	2.67	$	1.50	$	2.77
Trinidad	2.52		2.88		2.17		2.91
Other International ⁽²⁾	4.25		3.83		4.32		4.37
Composite	2.13		2.74		1.67		2.85
Crude Oil Equivalent Volumes (MBoed) ⁽⁴⁾
United States	784.3		695.0		833.8		722.0
Trinidad	44.1		44.1		34.0		45.1
Other International ⁽²⁾	5.8		9.7		6.3		6.5
Total	834.2		748.8		874.1		773.6

Total MMBoe ⁽⁴⁾	76.7		68.9		79.5		69.6


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


(2)	Other International includes EOG's ~~United Kingdom,~~ China and Canada operations. ~~The United Kingdom operations were sold in the fourth quarter of 2018.~~


(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.

Wellhead crude oil and condensate revenues for the ~~third~~first quarter of ~~2019~~2020 decreased ~~$236~~$135 million, or 9%6%, to ~~$2,419~~$2,065 million from ~~$2,655~~$2,200 million for the same period of ~~2018~~2019. The decrease was due to a lower composite average price ($~~550~~401 million), partially offset by an increase of 4947 MBbld, or ~~12%~~11%, in wellhead crude oil and condensate production ($~~314~~266 million). Increased production was primarily ~~due to increases~~ in the Permian ~~Basin and the Eagle Ford.~~Basin. EOG's composite wellhead crude oil and condensate price for the ~~third~~first quarter of ~~2019~~2020 decreased ~~19%~~16% to ~~$56.66~~$46.96 per barrel compared to ~~$69.55~~$56.09 per barrel for the same period of ~~2018~~2019.

NGL revenues for the ~~third~~first quarter of ~~2019~~2020 decreased ~~$189~~$58 million, or ~~53%~~26%, to ~~$165~~$161 million from ~~$354~~$219 million for the same period of ~~2018~~2019 due to a lower composite average price ($~~226~~137 million), partially offset by an increase of 1441 MBbld, or ~~11%~~35%, in production ($3779 million). Increased production was primarily in the Permian Basin. EOG's composite NGL price for the ~~third~~first quarter of ~~2019~~2020 decreased ~~58%~~46% to ~~$12.67~~$10.94 per barrel compared to ~~$30.09~~$20.28 per barrel for the same period of ~~2018.~~2019.

Wellhead natural gas revenues for the ~~third~~first quarter of ~~2019~~2020 decreased ~~$42~~$125 million, or ~~14%~~37%, to ~~$270~~$210 million from ~~$312~~$335 million for the same period of ~~2018~~2019. The decrease was due to a lower average composite price ($76147 million), partially offset by an increase in natural gas deliveries ($3422 million). Natural gas deliveries for the ~~third~~first quarter of ~~2019~~2020 increased ~~137~~70 MMcfd, or ~~11%~~5%, compared to the same period of ~~2018~~2019 due primarily to higher deliveries in the United States resulting from increased production of associated natural gas from the Permian Basin and higher natural gas volumes in South Texas, partially offset by lower volumes in Trinidad and the Marcellus Shale. EOG's composite wellhead natural gas price for the ~~third~~first quarter of ~~2019~~2020 decreased ~~22%~~41% to ~~$2.13~~$1.67 per Mcf compared to ~~$2.74~~$2.85 per Mcf for the same period of ~~2018~~2019.

During the ~~third~~first quarter of ~~2019~~2020, EOG recognized net gains on the mark-to-market of financial commodity derivative contracts of ~~$86~~$1,206 million compared to net losses of ~~$52~~$21 million for the same period of ~~2018~~2019. During the ~~third~~first quarter of ~~2019,~~2020, net cash received from settlements of financial commodity derivative contracts was ~~$108~~$84 million compared to net cash ~~paid~~received of ~~$92~~$21 million for the same period of ~~2018.~~2019.

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 ~~third~~first quarter of ~~2019~~2020 decreased ~~$43~~$86 million as compared to the same period of ~~2018~~2019 primarily due to lower margins on crude oil ~~marketing activities, partially offset by higher margins on natural gas~~ marketing activities.

Operating and Other Expenses. For the ~~third~~first quarter of ~~2019,~~2020, operating expenses of ~~$3,475~~$4,660 million were ~~$200~~$1,478 million higher than the ~~$3,275~~$3,182 million incurred during the ~~third~~first quarter of ~~2018.~~2019. The following table presents the costs per barrel of oil equivalent (Boe) for the three-month periods ended ~~September 30, 2019~~March 31, 2020 and ~~2018:~~2019:


	Three Months Ended September 30,				Three Months Ended March 31,
	2019		2018		2020		2019
Lease and Well	$	4.55	$	4.67	$	4.14	$	4.83
Transportation Costs	2.60		2.85		2.62		2.54
Depreciation, Depletion and Amortization (DD&A) -
Oil and Gas Properties	12.33		12.89		12.18		12.25
Other Property, Plant and Equipment	0.10		0.44		0.39		0.38
General and Administrative (G&A)	1.77		1.62		1.44		1.53
Interest Expense, Net	0.52		0.92		0.56		0.79
Total ⁽¹⁾	$	21.87	$	23.39	21.33		22.32


(1)	Total excludes gathering and processing costs, 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, G&A and net interest expense for the three months ended ~~September 30, 2019,~~March 31, 2020, compared to the same period of ~~2018,~~2019, are set forth below. See "Operating Revenues" above for a discussion of wellhead volumes.

Lease and well expenses include expenses for EOG-operated properties, as well as expenses billed to EOG from other operators where EOG is not the operator of a property. Lease and well expenses can be divided into the following categories: costs to operate and maintain crude oil and natural gas wells, the cost of workovers and lease and well administrative expenses. Operating and maintenance costs include, among other things, pumping services, 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 ~~$349~~$330 million for the ~~third~~first quarter of ~~2019 increased $27~~2020 decreased $6 million from ~~$322~~$336 million for the same prior year period primarily due to decreased workover expenditures in the United States ($10 million) and operating and maintenance costs in Canada ($6 million), partially offset by increased lease and well administrative expenses in the United States ($11 million).

Transportation costs represent costs associated with the delivery of hydrocarbon products from the lease 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 $208 million for the first quarter 2020 increased $31 million from $177 million for the same prior year period primarily due to increased ~~operating and maintenance~~transportation costs in the Permian Basin ($3335 million), South Texas ($5 million) and ~~lease and well administrative expenses~~Rocky Mountain area ($94 million) ~~in the United States,~~, partially offset by decreased ~~workover expenditures~~transportation costs in the ~~United States~~Barnett Shale ($9 million). ~~Lease and well expenses increased in the United States primarily due to increased operating activities resulting in increased production.~~

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

DD&A expenses for the ~~third~~first quarter of ~~2019~~2020 increased ~~$36~~$120 million to ~~$954~~$1,000 million from ~~$918~~$880 million for the same prior year period. DD&A expenses associated with oil and gas properties for the ~~third~~first quarter of ~~2019~~2020 were ~~$58~~$116 million higher than the same prior year period. The increase primarily reflects increased production in the United States ($~~109~~137 million), partially offset by lower unit rates in the United States ($4220 million) and decreased production in Trinidad ($5 million). Unit rates in the United States decreased primarily due to upward reserve revisions and reserves added at lower costs as a result of increased efficiencies.

G&A expenses of ~~$136~~$114 million for the ~~third~~first quarter of ~~2019~~2020 increased ~~$25~~$7 million from ~~$111~~$107 million for the same prior year period primarily due to increased ~~employee-related~~professional and other services ($6 million) and information ~~systems~~system costs ~~resulting from expanded operations.~~($3 million), partially offset by a decrease in employee-related costs ($2 million).

Interest expense, net of ~~$40~~$45 million for the ~~third~~first quarter of ~~2019~~2020 decreased ~~$24~~$10 million compared to the same prior year period primarily due to repayment in June 2019 of the $900 million aggregate principal amount of 5.625% Senior Notes due ~~2019 ($13 million), repayment in October 2018 of the $350 million aggregate principal amount of 6.875% Senior Notes due 2018 ($6 million) and higher capitalized interest ($4 million).~~2019.

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 ~~from~~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 ~~$14~~$17 million to $128 million for the ~~third~~first quarter of ~~2019~~2020 compared to ~~$114~~$111 million for the same prior year period primarily due to increased operating costs and fees in the Permian Basin ($1310 million) ~~and~~, the Eagle Ford ($5 million) and the Rocky Mountain area ($4 million).

Exploration costs of $40 million for the first quarter of 2020 increased $4 million from $36 million for the same prior year period due primarily to increased geological and geophysical expenditures ($2 million) and general and administrative expenses ($2 million), ~~partially offset by decreased operating costs~~all in the United ~~Kingdom ($7 million ) due to the sale of operations in the fourth quarter of 2018.~~

States.

Impairments ~~include~~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 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.

Impairments of ~~$105~~$1,573 million for the ~~third~~first quarter of ~~2019~~2020 were ~~$61~~$1,501 million higher than impairments for the same prior year period primarily due to commodity price declines that resulted in increased impairments of proved properties, leasehold costs and other assets, primarily related to legacy and non-core natural gas, crude oil and combo plays in the United States ($401,432 million), and ~~increased amortization~~in Canada ($60 million) as a result of ~~unproved property costs in~~ the ~~United States ($21 million), which were caused by an increase in EOG's estimates of undeveloped properties not expected~~decision to ~~be developed before lease expiration.~~exit the Horn River Basin. EOG recorded impairments of proved properties, other property, plant and equipment and other assets of ~~$41~~$1,456 million and $1$25 million for the ~~third~~first quarters of ~~2019~~2020 and ~~2018,~~2019, respectively.

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

Taxes other than income for the ~~third~~first quarter of ~~2019~~2020 decreased $6$36 million to ~~$203~~$157 million ~~(7.1%~~(6.5% of wellhead revenues) from ~~$209~~$193 million ~~(6.3%~~(7.0% of wellhead revenues) for the same prior year period. The decrease in taxes other than income was primarily due to decreased ad valorem/property taxes ($19 million), decreased severance/production taxes ~~in the United States~~ ($139 million) and an increase in credits available to EOG in the ~~third~~first quarter of ~~2019~~2020 for state incentive severance tax rate reductions ($39 million), ~~partially offset by higher payroll taxes in Trinidad ($8 million) and an increase in ad valorem/property taxes~~all in the United ~~States ($4 million).~~States.

Other income, net of $9$18 million for the ~~third~~first quarter of ~~2019~~2020 increased $6$12 million compared to the same prior year period primarily due to a decrease in deferred compensation ~~expense.~~expense ($14 million), partially offset by a decrease in foreign currency transaction gains ($2 million).

In response to the economic impacts of the COVID-19 pandemic, the President of the United States signed the Coronavirus Aid, Relief, and Economic Security Act (the CARES Act) into law on March 27, 2020. The CARES Act provides economic support to individuals and businesses through enhanced loan programs, expanded unemployment benefits, and certain payroll and income tax relief, among other provisions. The primary tax benefit of the CARES Act for EOG was the acceleration of approximately $150 million of additional refundable alternative minimum tax (AMT) credits into tax year 2019. These credits originated from AMT paid by EOG in years prior to 2018 and were reflected as a deferred tax asset and a non-current receivable as of December 31, 2019 since they had been expected to either offset future current tax liabilities or be refunded on a declining balance schedule through 2021. As a result of the CARES Act, EOG has reclassified these credits from a non-current receivable in Other Assets to a current receivable in Income Taxes Receivable on the Condensed Consolidated Balance Sheet at March 31, 2020.

EOG recognized an income tax provision of ~~$182~~$21 million for the ~~third~~first quarter of ~~2019~~2020 compared to an income tax provision of ~~$255~~$192 million for the ~~third~~first quarter of ~~2018,~~2019, primarily due to decreased pretax income. Additionally, the lower level of pretax income ~~partially offset by~~has caused the ~~absence of tax benefits from certain tax reform measurement-period adjustments. The net~~ effective tax rate ~~for 2019 increased to 23% from 18% in 2018. The higher effective tax rate is mostly due to the absence of tax benefits from certain tax reform measurement-period adjustments.~~

~~Nine Months Ended September 30, 2019 vs. Nine Months Ended September 30, 2018~~

~~Operating Revenues.~~ ~~During the first~~ ~~nine~~ ~~months of~~ ~~2019, operating revenues increased $359 million, or 3%, to $13,060 million from $12,701 million for the same period of~~ ~~2018. Total wellhead revenues for the first~~ ~~nine~~ ~~months of~~ ~~2019~~ ~~decreased $316 million, or 4%, to $8,592 million from $8,908 million for the same period of~~ ~~2018. During the first~~ ~~nine~~ ~~months of~~ ~~2019, EOG recognized net gains on the mark-to-market of financial commodity derivative contracts of $243 million compared to net losses of $298 million for the same period of~~ ~~2018. Gathering, processing and marketing revenues for the first~~ ~~nine~~ ~~months of~~ ~~2019~~ ~~increased $222 million, or 6%, to $4,121 million from $3,899 million for the same period of~~ ~~2018. Net gains on asset dispositions were $4 million for the first nine months of 2019 compared to net gains of $95 million for the same period of 2018.~~

~~Wellhead volume and price statistics for the nine-month periods ended September 30, 2019 and 2018 were as follows:~~

Nine Months Ended September 30,
2019 2018
Crude Oil and Condensate Volumes (MBbld)
United States 451.2
382.9

Trinidad 0.7
0.8

Other International 0.1
4.1

Total 452.0
387.8

Average Crude Oil and Condensate Prices ($/Bbl) ⁽¹⁾

United States $ 57.95
$ 67.35

Trinidad 47.26
58.91

Other International 58.43
71.83

Composite 57.93
67.38

Natural Gas Liquids Volumes (MBbld)
United States 130.8
113.9

Other International —
—

Total 130.8
113.9

Average Natural Gas Liquids Prices ($/Bbl)

United States $ 15.96
$ 27.71

Other International —
—

Composite 15.96
27.71

Natural Gas Volumes (MMcfd)
United States 1,043
905

Trinidad 267
278

Other International 36
31

Total 1,346
1,214

Average Natural Gas Prices ($/Mcf) ⁽¹⁾

United States $ 2.23
$ 2.66

Trinidad 2.71
2.91

Other International 4.29
4.10

Composite 2.38
2.75

Crude Oil Equivalent Volumes (MBoed)
United States 755.8
647.6

Trinidad 45.1
47.2

Other International 6.2
9.2

Total 807.1
704.0

Total MMBoe 220.3
192.2


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

~~Wellhead crude oil and condensate revenues for the first~~ ~~nine~~ ~~months of~~ ~~2019~~ ~~increased $14 million to $7,148 million from $7,134 million for the same period of~~ ~~2018~~ due to an increase of 64 MBbld, or 17%, in wellhead crude oil and condensate production ($1,185 million), partially offset by a lower composite average price ($1,171 million). Increased production was primarily due to increases in the Permian Basin and the Eagle Ford. EOG's composite wellhead crude oil and condensate price for the first ~~nine~~ ~~months of~~ ~~2019~~ ~~decreased 14% to $57.93 per barrel compared to $67.38 per barrel for the same period of~~ ~~2018~~.

~~NGL revenues for the first~~ ~~nine~~ ~~months of~~ ~~2019~~ ~~decreased $292 million, or 34%, to $570 million from $862 million for the same period of~~ ~~2018~~ due to a lower composite average price ($420 million), partially offset by an increase of 17 MBbld, or 15%, in NGL deliveries ($128 million). Increased production was primarily in the Permian Basin. EOG's composite NGL price for the first ~~nine~~ ~~months of~~ ~~2019~~ ~~decreased 42% to $15.96 per barrel compared to $27.71 per barrel for the same period of~~ ~~2018~~.

~~Wellhead natural gas revenues for the first~~ ~~nine~~ ~~months of~~ ~~2019~~ ~~decreased $38 million, or 4%, to $874 million from $912 million for the same period of~~ ~~2018~~. The decrease was due to a lower composite wellhead natural gas price ($140 million), partially offset by an increase in natural gas deliveries ($102 million). Natural gas deliveries for the first nine months of 2019 increased 132 MMcfd, or 11%, compared to the same period of 2018 due primarily to higher deliveries in the United States resulting from increased production of associated natural gas from the Permian Basin and higher natural gas volumes from South Texas. EOG's composite wellhead natural gas price for the first ~~nine~~ ~~months of~~ ~~2019~~ ~~decreased 14% to $2.38 per Mcf compared to $2.75 per Mcf for the same period of~~ ~~2018~~.

~~During the first~~ ~~nine~~ ~~months of~~ ~~2019, EOG recognized net gains on the mark-to-market of financial commodity derivative contracts of $243 million compared to net losses of $298 million for the same period of~~ ~~2018. During the first~~ ~~nine~~ ~~months of~~ ~~2019~~, net cash received from settlements of financial commodity derivative contracts was $140 million compared to net cash paid for settlements of financial commodity derivative contracts of $180 million for the same period of 2018.

~~Gathering, processing and marketing revenues less marketing costs for the first~~ ~~nine~~ ~~months of~~ ~~2019~~ ~~decreased $38 million as compared to the same period of~~ ~~2018~~ ~~primarily due to lower margins on crude oil marketing activities, partially offset by higher margins on natural gas marketing activities.~~

~~Operating and Other Expenses.~~ For the first nine months of 2019, operating expenses of $10,224 million were $869 million higher than the $9,355 million incurred during the same period of 2018. The following table presents the costs per Boe for the nine-month periods ended September 30, 2019 and 2018:

Nine Months Ended September 30,
2019 2018
Lease and Well $ 4.69
$ 4.87
Transportation Costs 2.50
2.87
DD&A -
Oil and Gas Properties 12.38
12.64
Other Property, Plant and Equipment 0.29
0.45
G&A 1.65
1.61
Interest Expense, Net 0.66
0.98
Total ⁽¹⁾
$ 22.17
$ 23.42


~~(1)~~	~~Total excludes gathering and processing costs, 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, DD&A, G&A and net interest expense for the nine months ended September 30, 2019, compared to the same period of 2018 are set forth below. See "Operating Revenues" above for a discussion of wellhead volumes.

Lease and well expenses of $1,032 million for the first nine months of 2019 increased $96 million from $936 million for the same prior year period primarily due to higher operating and maintenance costs ($81 million), higher lease and well administrative costs ($21 million) and higher workover expenditures ($8 million), all in the United States, partially offset by lower operating and maintenance costs in the United Kingdom ($11 million) due to the sale of operations in the fourth quarter of 2018. Lease and well expenses increased in the United States primarily due to increased operating activities resulting in increased production.

DD&A expenses for the first nine months of 2019 increased $275 million to $2,790 million from $2,515 million for the same prior year period. DD&A expenses associated with oil and gas properties for the first nine months of 2019 were $299 million higher than the same prior year period. The increase primarily reflects increased production in the United States ($384 million), partially offset by lower unit rates in the United States ($56 million). Unit rates in the United States decreased primarily due to upward reserve revisions and reserves added at lower costs as a result of increased efficiencies.

G&A expenses of $364 million for the first nine months of 2019 increased $54 million from $310 million for the same prior year period primarily due to increased employee-related and information systems expenses resulting from expanded operations.

Interest expense, net of $144 million for the first nine months of 2019 decreased $45 million compared to the same prior year period primarily due to repayment in October 2018 of the $350 million aggregate principal amount of 6.875% Senior Notes due 2018 ($18 million), repayment in June 2019 of the $900 million aggregate principal amount of 5.625% Senior Notes due 2019 ($17 million) and higher capitalized interest ($10 million).

Gathering and processing costs of $351 million for the first nine months of 2019 increased $27 million compared to the same prior year period primarily due to increased operating costs and fees in the Permian Basin ($41 million) and the Rocky Mountain area ($7 million), partially offset by decreased operating costs in the United Kingdom ($25 million) due to the sale of operations in the fourth quarter of 2018.

Exploration costs of $103 million for the first nine months of 2019 decreased $12 million from $115 million for the same prior year period primarily due to decreased geological and geophysical costs in Trinidad.

Impairments of $290 million for the first nine months of 2019 were $129 million higher than impairments for the same prior year period primarily due to increased impairments of proved properties and other assets in the United States ($98 million) and increased amortization of unproved property costs in the United States ($31 million), which was caused by an increase in EOG's estimate of undeveloped properties not expected to be ~~developed before lease expiration. EOG recorded impairments of proved properties, other property, plant and equipment and other assets of $132 million and $34 million for~~more sensitive to reconciling items; consequently, the ~~first nine months of 2019 and 2018, respectively.~~

Taxes other than income for the first nine months of 2019 increased $18 million to $600 million (7.0% of wellhead revenues) from $582 million (6.5% of wellhead revenues) for the same prior year period. The increase in taxes other than income was primarily due to increased ad valorem/property taxes in the United States ($41 million) primarily as a result of increased valuation of the underlying assets and higher payroll taxes in Trinidad ($8 million), partially offset by decreases in severance/production taxes in the United States ($14 million) and Trinidad ($4 million) and an increase in credits available to EOG in the first nine months of 2019 for state incentive severance tax rate reductions ($12 million).

Other income, net of $23 million for the first nine months of 2019 increased $28 million compared to the same prior year period primarily due to an increase in interest income ($14 million), a decrease in deferred compensation expense ($7 million) and higher foreign currency exchange gains ($6 million).

EOG recognized an income tax provision of $616 million for the first nine months of 2019 compared to an income tax provision of $626 million for the same period in 2018, primarily due to decreased pretax income, partially offset by the absence of tax benefits from certain tax reform measurement-period adjustments. The net effective tax rate for the first ~~nine months~~quarter of 2020 increased to 68% from 23% for the first quarter of 2019 ~~increased to 23% from 20% in 2018. The higher effective~~primarily as a result of certain foreign losses for which tax ~~rate is mostly~~benefits are not recorded due to ~~the absence of tax benefits from certain tax reform measurement-period adjustments.~~valuation allowances.

Capital Resources and Liquidity

Cash Flow. The primary sources of cash for EOG during the ~~nine~~three months ended ~~September 30, 2019~~March 31, 2020, 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; and other property, plant and equipment expenditures. During the first ~~nine~~three months of ~~2019~~2020, EOG's cash balance increased ~~$27~~$879 million to ~~$1,583~~$2,907 million from ~~$1,556~~$2,028 million at December 31, ~~2018~~2019.

Net cash provided by operating activities of ~~$6,356~~$2,585 million for the first ~~nine~~three months of ~~2019~~2020 increased ~~$673~~$977 million compared to the same period of ~~2018~~2019 primarily due to a favorable change in working capital ($~~474 million), a decrease in net cash paid for income taxes ($396~~1,420 million) and an increase in cash received for settlements of commodity derivative contracts ($~~320~~64 million), partially offset by a decrease in wellhead revenues ($~~315~~318 million), a decrease in gathering, processing and marketing revenues less marketing costs ($86 million), an increase in net cash paid for income taxes ($24 million) and an increase in cash operating expenses ($~~167~~28 million).

Net cash used in investing activities of ~~$4,980~~$1,531 million for the first ~~nine~~three months of ~~2019 increased~~2020 decreased by ~~$102~~$360 million compared to the same period of ~~2018~~2019 due to ~~an increase~~a decrease in additions to oil and gas properties ($~~295~~373 million), ~~partially offset by~~ a favorable change in components of working capital associated with investing activities ($~~134~~38 million), and an increase in proceeds from the sale of assets ($2411 million), ~~a decrease in other investing activities ($20 million) and a decrease~~partially offset by an increase in additions to other property, plant and equipment ($1562 million).

Net cash used in financing activities of ~~$1,348~~$175 million for the first ~~nine~~three months of ~~2019~~2020 included ~~repayments of long-term debt ($900 million) and~~ cash dividend payments ($~~421~~167 million), purchases of treasury stock in connection with stock compensation plans ($5 million) and repayment of finance lease liabilities ($4 million). Net cash used in financing activities of ~~$363~~$137 million for the first ~~nine~~three months of ~~2018~~2019 included cash dividend payments ($~~311~~128 million) and purchases of treasury stock in connection with stock compensation plans ($596 million).

Total Expenditures. For the year ~~2019,~~2020, EOG's updated budget for exploration and development and other property, plant and equipment expenditures is estimated to range from approximately ~~$6.2~~$3.3 billion to ~~$6.4~~$3.7 billion, excluding acquisitions and non-cash transactions. The table below sets out components of total expenditures for the ~~nine-month~~three-month periods ended ~~September 30,~~March 31, 2020 and 2019 ~~and 2018~~ (in millions):


	Nine Months Ended September 30,				Three Months Ended March 31,
	2019		2018		2020		2019
Expenditure Category
Capital
Exploration and Development Drilling	$	3,865	$	3,843	$	1,313	$	1,402
Facilities	499		518		179		164
Leasehold Acquisitions ⁽¹⁾	201		331		45		107
Property Acquisitions ⁽²⁾	332		79		48		321
Capitalized Interest	28		18		9		7
Subtotal	4,925		4,789		1,594		2,001
Exploration Costs	103		115		40		36
Dry Hole Costs	28		5		—		—
Exploration and Development Expenditures	5,056		4,909		1,634		2,037
Asset Retirement Costs	151		42		20		4
Total Exploration and Development Expenditures	5,207		4,951		1,654		2,041
Other Property, Plant and Equipment ⁽³⁾	187		251		172		61
Total Expenditures	$	5,394	$	5,202	$	1,826	$	2,102


(1)	Leasehold acquisitions included ~~$64~~$24 million and ~~$162~~$44 million for the ~~nine-month~~three-month periods ended ~~September 30,~~March 31, 2020 and 2019, ~~and 2018,~~ respectively, related to non-cash property exchanges.


(2)	Property acquisitions included ~~$21~~$5 million and ~~$60~~$18 million for the ~~nine-month~~three-month periods ended ~~September 30,~~March 31, 2020 and 2019, ~~and 2018,~~ respectively, related to non-cash property exchanges.


(3)	Other property, plant and equipment included $49 million of non-cash additions for the ~~nine-month~~three-month period ended ~~September 30, 2018~~March 31, 2020 made in connection with a finance lease ~~transaction in the Permian Basin.~~transaction.

Exploration and development expenditures of ~~$5,056~~$1,634 million for the first ~~nine~~three months of ~~2019~~2020 were ~~$147~~$403 million ~~higher~~lower than the same period of ~~2018~~2019 primarily due to ~~increased~~decreased property acquisitions ($~~253~~273 million), decreased exploration and development drilling expenditures in the United States ($99 million) and Other International ($9 million), decreased leasehold acquisitions ($62 million), partially offset by increased exploration and development drilling expenditures in Trinidad ($~~28 million), partially offset by decreased leasehold acquisitions ($130~~20 million) and ~~decreased~~increased facilities expenditures ($1915 million). Exploration and development expenditures for the first ~~nine~~three months of ~~2019~~2020 of ~~$5,056~~$1,634 million consisted of ~~$4,341~~$1,465 million in development drilling and facilities, ~~$355~~$112 million in exploration, ~~$332~~$48 million in property acquisitions and ~~$28~~$9 million in capitalized interest. Exploration and development expenditures for the first ~~nine~~three months of ~~2018~~2019 of ~~$4,909~~$2,037 million consisted of ~~$4,353~~$1,555 million in development drilling and facilities, ~~$459 million in exploration, $79~~$321 million in property acquisitions, $154 million in exploration and ~~$18~~$7 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.

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, ~~2018,~~2019, filed on February ~~26, 2019,~~27, 2020, 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 ~~September 30, 2019,~~March 31, 2020, as a net asset of ~~$123~~$933 million.

Crude Oil Derivative Contracts.Prices received by EOG for its crude oil production generally vary from NYMEX ~~West Texas Intermediate~~WTI prices due to adjustments for delivery location (basis) and other factors. EOG has entered into crude oil basis swap contracts in order to fix the differential between Intercontinental Exchange (ICE) Brent pricing and pricing in ~~Midland, Texas, and~~ Cushing, Oklahoma ~~(Midland~~(ICE Brent Differential). Presented below is a comprehensive summary of EOG's ~~Midland~~ICE Brent Differential basis swap contracts through ~~October 29, 2019.~~May 5, 2020. The weighted average price differential expressed in dollars per barrel ($/Bbl) represents the amount of ~~reduction~~addition to Cushing, Oklahoma, prices for the notional volumes expressed in barrels per day (Bbld) covered by the basis swap contracts.

Midland Differential Basis Swap Contracts
Volume (Bbld)
Weighted Average Price Differential
($/Bbl)

2019
January 1, 2019 through November 30, 2019 (closed) 20,000
$ 1.075
December 2019 20,000
1.075



ICE Brent Differential Basis Swap Contracts
	Volume (Bbld)	Weighted Average Price Differential ($/Bbl)


2020
May 2020	10,000	$	4.92

EOG has also entered into crude oil basis swap contracts in order to fix the differential between pricing in ~~the U.S. Gulf Coast~~Houston, Texas, and Cushing, Oklahoma ~~(Gulf Coast~~(Houston Differential). Presented below is a comprehensive summary of EOG's ~~Gulf Coast~~Houston Differential basis swap contracts through ~~October 29, 2019.~~May 5, 2020. The weighted average price differential expressed in $/Bbl represents the amount of addition to Cushing, Oklahoma, prices for the notional volumes expressed in Bbld covered by the basis swap contracts.

Gulf Coast Differential Basis Swap Contracts
Volume (Bbld)
Weighted Average Price Differential
($/Bbl)

2019
January 1, 2019 through November 30, 2019 (closed) 13,000
$ 5.572
December 2019 13,000
5.572



Houston Differential Basis Swap Contracts
	Volume (Bbld)	Weighted Average Price Differential ($/Bbl)


2020
May 2020 (closed)	10,000	$	1.55

EOG has also entered into crude oil swaps to fix the differential in pricing between the NYMEX calendar month average and the physical crude oil delivery month (Roll Differential). Presented below is a comprehensive summary of EOG's Roll Differential swap contracts through May 5, 2020. The weighted average price differential expressed in $/Bbl represents the amount of net addition (reduction) to delivery month prices for the notional volumes expressed in Bbld covered by the swap contracts.



Roll Differential Swap Contracts
	Volume (Bbld)	Weighted Average Price Differential ($/Bbl)


2020
February 1, 2020 through May 31, 2020 (closed)	10,000	$	0.70
June 2020	10,000	0.70
July 1, 2020 through September 30, 2020	110,000	(1.16		)
October 1, 2020 through December 31, 2020	93,000	(1.16		)

In May 2020, EOG entered into crude oil Roll Differential contracts for the period from October 1, 2020 through December 31, 2020, with notional volumes of 17,000 Bbld at a weighted average price differential of $(1.01) per Bbl. These contracts partially offset certain outstanding Roll Differential contracts for the same time period with notional volumes of 17,000 Bbld at a weighted average price differential of $(1.16) per Bbl. EOG expects to pay net cash of $0.2 million for the settlement of these contracts. The offsetting contracts were excluded from the above table.

Presented below is a comprehensive summary of EOG's crude oil NYMEX WTI price swap contracts through ~~October 29, 2019,~~May 5, 2020, with notional volumes expressed in Bbld and prices expressed in $/Bbl.



Crude Oil NYMEX WTI Price Swap Contracts
	Volume (Bbld)	Weighted Average Price ($/Bbl)


2020
January 1, 2020 through March 31, 2020 (closed)	200,000	$	59.33
April 2020 (closed)	265,000	51.36
May 1, 2020 through June 30, 2020	265,000	51.36
July 2020	254,000	42.36
August 1, 2020 through September 30, 2020	154,000	50.42

In April and May 2020, EOG entered into crude oil NYMEX WTI price swap contracts for the period from October 1, 2020 through December 31, 2020, with notional volumes of 47,000 Bbld at a weighted average price of $30.04 per Bbl. These contracts offset the remaining NYMEX WTI price swap contracts for the same time period with notional volumes of 47,000 Bbld at a weighted average price of $31.00 per Bbl. EOG expects to receive net cash of $4.1 million for the settlement of these contracts. The offsetting contracts were excluded from the above table.

Presented below is a comprehensive summary of EOG's crude oil ICE Brent price swap contracts through May 5, 2020, with notional volumes expressed in Bbld and prices expressed in $/Bbl.



Crude Oil ICE Brent Price Swap Contracts
	Volume (Bbld)	Weighted Average Price ($/Bbl)


2020
April 2020 (closed)	75,000	$	25.66
May 2020	35,000	26.53

NGLs Derivative Contracts. Presented below is a comprehensive summary of EOG's Mont Belvieu propane (non-TET) financial price swap contracts (Mont Belvieu Propane Price Swap Contracts) through May 5, 2020, with notional volumes expressed in Bbld and prices expressed in $/Bbl.



Mont Belvieu Propane Price Swap Contracts
	Volume (Bbld)	Weighted Average Price ($/Bbl)


2020
January 1, 2020 through February 29, 2020 (closed)	4,000	$	21.34
March 1, 2020 through April 30, 2020 (closed)	25,000	17.92
May 1, 2020 through December 31, 2020	7,000	17.92

In April and May 2020, EOG entered into Mont Belvieu Propane Price Swap Contracts for the period from May 1, 2020 through December 31, 2020, with notional volumes of 18,000 Bbld at a weighted average price of $15.68 per Bbl. These contracts partially offset certain outstanding Mont Belvieu Propane Price Swap Contracts for the same time period with notional volumes of 18,000 Bbld at a weighted average price of $17.92 per Bbl. EOG expects to receive net cash of $9.9 million for the settlement of these contracts. The offsetting contracts were excluded from the above table.

Natural Gas Derivative Contracts. Presented below is a comprehensive summary of EOG's natural gas price swap contracts through May 5, 2020, with notional volumes expressed in million British thermal units (MMBtu) per day (MMBtud) and prices expressed in dollars per MMBtu ($/MMBtu).



Natural Gas Price Swap Contracts
	Volume (MMBtud)	Weighted Average Price ($/MMBtu)


2021
January 1, 2021 through December 31, 2021	50,000	$	2.75

EOG has entered into natural gas collar contracts, which establish ceiling and floor prices for the sale of notional volumes of natural gas as specified in the collar contracts. The collars require that EOG pay the difference between the ceiling price and the NYMEX Henry Hub natural gas price for the contract month (Henry Hub Index Price) in the event the Henry Hub Index Price is above the ceiling price. The collars grant EOG the right to receive the difference between the floor price and the Henry Hub Index Price in the event the Henry Hub Index Price is below the floor price. On March 24, 2020, EOG executed the early termination provision granting EOG the right to terminate certain 2020 natural gas collar contracts with notional volumes of 250,000 MMBtud at a weighted average ceiling price of $2.50 per MMBtu and a weighted average floor price of $2.00 per MMBtu for the period from April 1, 2020 through July 31, 2020. The net cash EOG received for settling these contracts was $7.8 million. Presented below is a comprehensive summary of EOG's natural gas collar contracts through May 5, 2020, with notional volumes expressed in MMBtud and prices expressed in $/MMBtu.



Natural Gas Collar Contracts
		Weighted Average Price ($/MMBtu)
	Volume (MMBtud)	Ceiling Price		Floor Price


2020
April 1, 2020 through July 31, 2020 (closed)	250,000	$	2.50	$	2.00

On April 14, 2020, EOG entered into natural gas collar contracts for the period from August 1, 2020 through October 31, 2020, with notional volumes of 250,000 MMBtud at a ceiling price of $2.50 per MMBtu and a floor price of $2.00 per MMBtu. These contracts offset the remaining natural gas collar contracts for the same time period with notional volumes of 250,000 MMBtud at a ceiling price of $2.50 per MMBtu and a floor price of $2.00 per MMBtu. EOG expects to receive net cash of $1.1 million for the settlement of these contracts. The offsetting contracts were excluded from the above table.

Prices received by EOG for its natural gas production generally vary from NYMEX Henry Hub prices due to adjustments for delivery location (basis) and other factors. EOG has entered into natural gas basis swap contracts in order to fix the differential between pricing in the Rocky Mountain area and NYMEX Henry Hub prices (Rockies Differential). Presented below is a comprehensive summary of EOG's Rockies Differential basis swap contracts through ~~October 29, 2019.~~May 5, 2020. The weighted average price differential expressed in ~~dollars per million British thermal units ($/MMBtu)~~$/MMBtu represents the amount of reduction to NYMEX Henry Hub prices for the notional volumes expressed in ~~MMBtu per day (MMBtud)~~MMBtud covered by the basis swap contracts.

Rockies Differential Basis Swap Contracts
Volume (MMBtud)
Weighted Average Price Differential
($/MMBtu)

2020
January 1, 2020 through December 31, 2020 30,000
$ 0.549



Rockies Differential Basis Swap Contracts
	Volume (MMBtud)	Weighted Average Price Differential ($/MMBtu)


2020
January 1, 2020 through May 31, 2020 (closed)	30,000	$	0.55
June 1, 2020 through December 31, 2020	30,000	0.55

EOG has also entered into natural gas basis swap contracts in order to fix the differential between pricing at the Houston Ship Channel (HSC) and NYMEX Henry Hub prices (HSC Differential). On March 27, 2020, EOG executed the early termination provision granting EOG the right to terminate certain 2020 HSC Differential basis swaps with notional volumes of 60,000 MMBtud at a weighted average price differential of $0.05 per MMBtu for the period from April 1, 2020 through December 31, 2020. The net cash EOG paid for settling these contracts was $0.4 million. Presented below is a comprehensive summary of EOG's ~~natural gas price~~HSC Differential basis swap contracts through ~~October 29, 2019, with~~May 5, 2020. The weighted average price differential expressed in $/MMBtu represents the amount of reduction to NYMEX Henry Hub prices for the notional volumes expressed in MMBtud covered by the basis swap contracts.



HSC Differential Basis Swap Contracts
	Volume (MMBtud)	Weighted Average Price Differential ($/MMBtu)


2020
January 1, 2020 through December 31, 2020 (closed)	60,000	$	0.05

EOG has also entered into natural gas basis swap contracts in order to fix the differential between pricing at the Waha Hub in West Texas and NYMEX Henry Hub prices (Waha Differential). Presented below is a comprehensive summary of EOG's Waha Differential basis swap contracts through May 5, 2020. The weighted average price differential expressed in $/~~MMBtu.~~MMBtu represents the amount of reduction to NYMEX Henry Hub prices for the notional volumes expressed in MMBtud covered by the basis swap contracts.

Natural Gas Price Swap Contracts
Volume (MMBtud)
Weighted
Average Price
($/MMBtu)
2019
April 1, 2019 through October 31, 2019 (closed) 250,000
$ 2.90



Waha Differential Basis Swap Contracts
	Volume (MMBtud)	Weighted Average Price Differential ($/MMBtu)


2020
January 1, 2020 through April 30, 2020 (closed)	50,000	$	1.40

In April 2020, EOG entered into Waha Differential basis swap contracts for the period from May 1, 2020 through December 31, 2020, with notional volumes of 50,000 MMBtud at a weighted average price differential of $0.43 per MMBtu. These contracts offset the remaining Waha Differential basis swap contracts for the same time period with notional volumes of 50,000 MMBtud at a weighted average price differential of $1.40 MMBtu. EOG expects to pay net cash of $11.9 million for the settlement of these contracts. The offsetting contracts were excluded from the above table.

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, returns, 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,"~~“aims,” "goal," "may," "will," "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, 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;

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;~~projects and associated potential and existing drilling locations;

the extent to which EOG is successful in its efforts to market its crude oil and condensate, natural gas liquids, natural gas and related commodity production;

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 and refining 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 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 imposing 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 and transportation 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;

~~physical, electronic and cybersecurity breaches;~~ and

the other factors described under ITEM 1A, Risk Factors, on pages 13 through 2223 of EOG's Annual Report on Form 10-K for the fiscal year ended December 31, ~~2018,~~2019 and under ITEM 1A, Risk Factors, in this Quarterly Report on Form 10-Q, 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.

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 ~~"Derivative~~"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 40 through 4346 of EOG's Annual Report on Form 10-K for the year ended December 31, ~~2018,~~2019, filed on February ~~26,~~27, 2020 (EOG's 2019 ~~(EOG's 2018~~ Annual Report); and (ii) Note 12, "Risk Management Activities," to EOG's Consolidated Financial Statements on pages ~~F-29~~F-30 through ~~F-31~~F-33 of EOG's ~~2018~~2019 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.

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 1A. RISK FACTORS

There have been no material changes from the risk factors disclosed in Item 1A. Risk Factors of our Annual Report on Form 10-K for the year ended December 31, 2019, other than the following:

Outbreaks of communicable diseases could adversely affect our business, financial condition and results of operations.

Global or national health concerns, including a widespread outbreak of contagious disease, can negatively impact the global economy, reduce demand and pricing for crude oil, natural gas liquids (NGLs) and natural gas, lead to operational disruptions and limit our ability to execute on our business plan, which could materially and adversely affect our business, financial condition and results of operations. Furthermore, uncertainty regarding the impact of any outbreak of contagious disease could lead to increased volatility in crude oil, NGLs and natural gas prices. For example, the recent pandemic involving a highly transmissible and pathogenic coronavirus (COVID-19) and the measures being taken to address and limit the spread of the virus have adversely affected the economies and financial markets of many countries, resulting in an economic downturn that has negatively impacted, and may continue to negatively impact, global demand and prices for crude oil and NGLs. If the COVID-19 outbreak should worsen, we may also experience disruptions to commodities markets, equipment supply chains and the availability of our workforce, which could adversely affect our ability to conduct our business and operations. There are still too many variables and uncertainties regarding the COVID-19 pandemic - including the ultimate geographic spread of the virus, the duration and severity of the outbreak and the extent of travel restrictions and business closures imposed in affected countries - to fully assess the potential impact on our business and operations.

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⁾

July 1, 2019 - July 31, 2019 17,498
$ 92.82
—
6,386,200
August 1, 2019 - August 31, 2019 11,181
73.92
—
6,386,200
September 1, 2019 - September 30, 2019 149,912
75.87
—
6,386,200
Total 178,591
77.41
—



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⁾
Period	Total Number of Shares Purchased ⁽¹⁾	Average Price Paid Per Share

January 1, 2020 - January 31, 2020	6,332	$	80.72	—	6,386,200
February 1, 2020 - February 29, 2020	20,779	74.64		—	6,386,200
March 1, 2020 - March 31, 2020	67,681	38.24		—	6,386,200
Total	94,792	49.05		—

(1)

The ~~178,591~~94,792 total shares for the quarter ended ~~September 30, 2019,~~March 31, 2020, 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 ~~third~~first quarter of ~~2019,~~2020, EOG did not repurchase any shares under the Board-authorized repurchase program.

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.

ITEM 6. EXHIBITS



Exhibit No.		Description

3.1(a)	-	Restated Certificate of Incorporation, dated September 3, 1987 (incorporated by reference to Exhibit 3.1(a) to EOG's Annual Report on Form 10-K for the year ended December 31, 2008) (SEC File No. 001-09743).

3.1(b)	-	Certificate of Amendment of Restated Certificate of Incorporation, dated May 5, 1993 (incorporated by reference to Exhibit 4.1(b) to EOG's Registration Statement on Form S-8, SEC File No. 33-52201, filed February 8, 1994).

3.1(c)	-	Certificate of Amendment of Restated Certificate of Incorporation, dated June 14, 1994 (incorporated by reference to Exhibit 4.1(c) to EOG's Registration Statement on Form S-8, SEC File No. 33-58103, filed March 15, 1995).

3.1(d)	-	Certificate of Amendment of Restated Certificate of Incorporation, dated June 11, 1996 (incorporated by reference to Exhibit 3(d) to EOG's Registration Statement on Form S-3, SEC File No. 333-09919, filed August 9, 1996).

3.1(e)	-	Certificate of Amendment of Restated Certificate of Incorporation, dated May 7, 1997 (incorporated by reference to Exhibit 3(e) to EOG's Registration Statement on Form S-3, SEC File No. 333-44785, filed January 23, 1998).

3.1(f)	-	Certificate of Ownership and Merger Merging EOG Resources, Inc. into Enron Oil & Gas Company, dated August 26, 1999 (incorporated by reference to Exhibit 3.1(f) to EOG's Annual Report on Form 10-K for the year ended December 31, 1999) (SEC File No. 001-09743).

3.1(g)	-	Certificate of Designations of Series E Junior Participating Preferred Stock, dated February 14, 2000 (incorporated by reference to Exhibit 2 to EOG's Registration Statement on Form 8-A, SEC File No. 001-09743, filed February 18, 2000).

3.1(h)	-	Certificate of Elimination of the Fixed Rate Cumulative Perpetual Senior Preferred Stock, Series A, dated September 13, 2000 (incorporated by reference to Exhibit 3.1(j) to EOG's Registration Statement on Form S-3, SEC File No. 333-46858, filed September 28, 2000).

3.1(i)	-	Certificate of Elimination of the Flexible Money Market Cumulative Preferred Stock, Series C, dated September 13, 2000 (incorporated by reference to Exhibit 3.1(k) to EOG's Registration Statement on Form S-3, SEC File No. 333-46858, filed September 28, 2000).

3.1(j)	-	Certificate of Elimination of the Flexible Money Market Cumulative Preferred Stock, Series D, dated February 24, 2005 (incorporated by reference to Exhibit 3.1(k) to EOG's Annual Report on Form 10-K for the year ended December 31, 2004) (SEC File No. 001-09743).

3.1(k)	-	Amended Certificate of Designations of Series E Junior Participating Preferred Stock, dated March 7, 2005 (incorporated by reference to Exhibit 3.1(m) to EOG's Annual Report on Form 10-K for the year ended December 31, 2007) (SEC File No. 001-09743).

3.1(l)	-	Certificate of Amendment of Restated Certificate of Incorporation, dated May 3, 2005 (incorporated by reference to Exhibit 3.1(l) to EOG's Quarterly Report on Form 10-Q for the quarter ended June 30, 2005) (SEC File No. 001-09743).

3.1(m)	-	Certificate of Elimination of Fixed Rate Cumulative Perpetual Senior Preferred Stock, Series B, dated March 6, 2008 (incorporated by reference to Exhibit 3.1 to EOG's Current Report on Form 8-K, filed March 6, 2008) (SEC File No. 001-09743).

3.1(n)	-	Certificate of Amendment of Restated Certificate of Incorporation, dated April 28, 2017 (incorporated by reference to Exhibit 3.1 to EOG's Current Report on Form 8-K, filed May 2, 2017) (SEC File No. 001-09743).

3.2	-	Bylaws, dated August 23, 1989, as amended and restated effective as of September 22, 2015 (incorporated by reference to Exhibit 3.1 to EOG's Current Report on Form 8-K, filed September 28, 2015) (SEC File No. 001-09743).

~~10.1~~4.1	-	Officers' Certificate Establishing 4.375% Senior Notes due 2030 and 4.950% Senior Notes due 2050 of EOG, dated April 14, 2020 (incorporated by reference to Exhibit 4.2 to EOG's Current Report on Form 8-K, filed April 14, 2020) (SEC File No. 001-09743).

4.2	-	Form of ~~Performance Unit Award Agreement for Amended~~Global Note with respect to the 4.375% Senior Notes due 2030 of EOG (included in, and ~~Restated~~incorporated by reference to, Exhibit 4.2 to EOG's Current Report on Form 8-K, filed April 14, 2020) (SEC File No. 001-09743).



Exhibit No.		Description

4.3	-	Form of Global Note with respect to the 4.950% Senior Notes due 2050 of EOG ~~Resources, Inc. 2008 Omnibus Equity Compensation Plan (applicable~~(included in, and incorporated by reference to, ~~grants made effective September 26, 2019 and subsequent grants)~~Exhibit 4.2 to EOG's Current Report on Form 8-K, filed April 14, 2020) (SEC File No. 001-09743).

31.1	-	Section 302 Certification of Periodic Report of Principal Executive Officer.

31.2	-	Section 302 Certification of Periodic Report of Principal Financial Officer.

32.1	-	Section 906 Certification of Periodic Report of Principal Executive Officer.



~~Exhibit No.~~		~~Description~~

32.2	-	Section 906 Certification of Periodic Report of Principal Financial Officer.

95	-	Mine Safety Disclosure Exhibit.

101.INS	-	Inline XBRL Instance Document - the instance document does not appear in the Interactive Data File because its XBRL tags are embedded within the Inline XBRL document.

*101.SCH	-	Inline XBRL Schema Document.

*101.CAL	-	Inline XBRL Calculation Linkbase Document.

*101.DEF	-	Inline XBRL Definition Linkbase Document.

*101.LAB	-	Inline XBRL Label Linkbase Document.

*101.PRE	-	Inline XBRL Presentation Linkbase Document.

104	-	Cover Page Interactive Data File (formatted as Inline XBRL and contained in Exhibit 101).

*Attached as Exhibit 101 to this report are the following documents formatted in XBRL (Extensible Business Reporting Language): (i) the Condensed Consolidated Statements of Income and Comprehensive Income - Three ~~and Nine~~ Months Ended ~~September 30,~~March 31, 2020 and 2019, ~~and 2018,~~ (ii) the Condensed Consolidated Balance Sheets - ~~September 30, 2019~~March 31, 2020 and December 31, ~~2018,~~2019, (iii) the Condensed Consolidated Statements of Stockholders' Equity - Three ~~and Nine~~ Months Ended ~~September 30,~~March 31, 2020 and 2019, ~~and 2018,~~ (iv) the Condensed Consolidated Statements of Cash Flows - ~~Nine~~Three Months Ended ~~September 30,~~March 31, 2020 and 2019 ~~and 2018~~ and (v) the Notes to Condensed Consolidated Financial Statements.

SIGNATURES

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



			EOG RESOURCES, INC.
			(Registrant)



Date:	~~November 6, 2019~~May 7, 2020	By:	/s/ TIMOTHY K. DRIGGERS Timothy K. Driggers Executive Vice President and Chief Financial Officer (Principal Financial Officer and Duly Authorized Officer)

~~-40-~~-41-



Crude Oil Price Swap Contracts
	Volume (Bbld)	Weighted Average Price ($/Bbl)
2019
April 2019 (closed)	25,000	$	60.00
May 1, 2019 through September 30, 2019 (closed)	150,000	62.50
October 1, 2019 through December 31, 2019	150,000	62.50



	Three Months Ended September 30, 2019		Nine Months Ended September 30, 2019
Operating Lease Cost	$	138	$	391
Finance Lease Cost:
Amortization of Lease Assets	3		10
Interest on Lease Liabilities	—		1
Variable Lease Cost	39		167
Short-Term Lease Cost	67		295
Total Lease Cost	$	247	$	864



Description	Location on Balance Sheet	Amount
Assets
Operating Leases	Other Assets	$	842
Finance Leases	Property, Plant and Equipment, Net ⁽¹⁾	56
Total		$	898

Liabilities
Current
Operating Leases	Current Portion of Operating Lease Liabilities	$	384
Finance Leases	Current Portion of Long-Term Debt	15
Long-Term
Operating Leases	Other Liabilities	485
Finance Leases	Long-Term Debt	46
Total		$	930



	Nine Months Ended September 30, 2019
Repayment of Operating Lease Liabilities Associated with Operating Activities	$	162
Repayment of Operating Lease Liabilities Associated with Investing Activities	225
Repayment of Finance Lease Liabilities	10



	Operating Leases		Finance Leases
October 1, 2019 to December 31, 2019	$	116	$	3
2020	377		15
2021	198		15
2022	118		12
2023	50		8
2024 and Beyond	64		14
Total Lease Payments	923		67
Less: Discount to Present Value	54		6
Total Lease Liabilities	869		61
Less: Current Portion of Lease Liabilities	384		15
Long-Term Lease Liabilities	$	485	$	46



Natural Gas Price Swap Contracts
	Volume (MMBtud)	Weighted Average Price ($/MMBtu)
2019
April 1, 2019 through October 31, 2019 (closed)	250,000	$	2.90