EOG EOG Resources Inc

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(1)	The total intrinsic value of stock options/SARs exercised for the nine months ended September 30, 2018 and 2017 was $103.7 million and $66.6 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, 2018 and 2017 was $269.1 million and $147.8 million, respectively. At September 30, 2018 and 2017, the weighted average remaining contractual life was 4.8 years and 4.3 years, respectively.

(3)	The total intrinsic value of stock options/SARs vested or expected to vest at September 30, 2018 and 2017 was $261.9 million and $145.9 million, respectively. At September 30, 2018 and 2017, the weighted average remaining contractual life was 4.7 years and 4.3 years, respectively.

(4)	The total intrinsic value of stock options/SARs exercisable at September 30, 2018 and 2017 was $175.5 million and $123.2 million, respectively. At September 30, 2018 and 2017, the weighted average remaining contractual life was 3.4 years and 2.8 years, respectively.

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(1)	The total intrinsic value of restricted stock and restricted stock units released for the nine months ended September 30, 2018 and 2017 was $80.2 million and $81.6 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, 2018 and 2017 was $489.7 million and $386.6 million, respectively.

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(1)	Upon completion of the Performance Period for the Performance Awards granted in 2014 and 2013, a performance multiple of 200% was applied to each of the grants resulting in additional grants of Performance Awards in February 2018 and February 2017, respectively.

(2)	The total intrinsic value of Performance Awards released during the nine months ended September 30, 2018 and 2017 was approximately $17.7 million and $23.6 million, respectively. The intrinsic value is based upon the closing price of EOG's common stock on the date the Performance Awards are released.

(3)	The total intrinsic value of Performance Awards outstanding at September 30, 2018 and 2017 was approximately $68.0 million and $48.6 million, respectively.

(4)	Upon the application of the relevant performance multiple at the completion of each of the remaining Performance Periods, a minimum of 143,610 and a maximum of 921,940 Performance Awards could be outstanding.

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(1)	Net of capitalized interest of $18 million and $21 million for the nine months ended September 30, 2018 and 2017, respectively.

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

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

(1)	Includes settlements related to asset sales.

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(1)	The current portion of Liabilities from Price Risk Management Activities consists of gross liabilities of $161 million, partially offset by gross assets of $28 million at September 30, 2018, and gross liabilities of $55 million, partially offset by gross assets of $5 million at December 31, 2017.

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(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.

(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)

Includes a positive revenue adjustment of $0.49 per Mcf related to the adoption of ASU 2014-09, "Revenue From Contracts with Customers" (ASU 2014-09) (see Note 1 to the Condensed Consolidated Financial Statements). In connection with the adoption of ASU 2014-09, EOG presents natural gas processing fees relating to certain processing and marketing agreements as Gathering and Processing Costs, instead of as a deduction to Natural Gas revenues.

(5)

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.

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

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

(2)	Includes a positive revenue adjustment of $0.43 per Mcf related to the adoption of ASU 2014-09 (see Note 1 to the Condensed Consolidated Financial Statements). In connection with the adoption of ASU 2014-09, EOG presents natural gas processing fees relating to certain processing and marketing agreements as Gathering and Processing Costs, instead of as a deduction to Natural Gas revenues.

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

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(1)	Leasehold acquisitions included $162 million and $214 million for the nine-month periods ended September 30, 2018 and 2017, respectively, related to non-cash property exchanges.

(2)	Property acquisitions included $60 million for the nine-month period ended September 30, 2018 related to non-cash property exchanges.

(3)	Other property, plant and equipment included $49 million of non-cash additions for the nine-month period ended September 30, 2018, primarily related to a capital lease transaction in the Permian Basin.

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•	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 economically develop its acreage in, produce reserves and achieve anticipated production levels from, and maximize reserve recovery from, its existing and future crude oil and natural gas exploration and development projects;

•	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;

•	the availability, proximity and capacity of, and costs associated with, appropriate gathering, processing, compression, 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; 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 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 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 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;

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•	political conditions and developments around the world (such as 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 cyber security breaches; and

•	the other factors described under ITEM 1A, Risk Factors, on pages 14 through 23 of EOG's Annual Report on Form 10-K for the fiscal year ended December 31, 2017, 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.

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(1)

The 218,169 total shares for the quarter ended September 30, 2018, and the 499,650 total shares for the nine months ended September 30, 2018, 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 quarter of 2018, EOG did not repurchase any shares under the Board-authorized repurchase program.

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•	Annual Report

•	Proxy Statement

•	Amended and Restated EOG Resources, Inc. 2008 Omnibus Equity Compensation Plan

•	Written Notice form

•	Code of Business Conduct and Ethics

•	Conflicts of Interest Policy

•	Policy on Confidential Information

•	Policy on Inventions

•	Information Systems Security Policy

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•	Annual Report

•	Proxy Statement

•	Amended and Restated EOG Resources, Inc. 2008 Omnibus Equity Compensation Plan

•	Written Notice form

•	Code of Business Conduct and Ethics

•	Conflicts of Interest Policy

•	Policy on Confidential Information

•	Policy on Inventions

•	Information Systems Security Policy

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•	Annual Report

•	Proxy Statement

•	Amended and Restated EOG Resources, Inc. 2008 Omnibus Equity Compensation Plan

•	Code of Business Conduct and Ethics

•	Conflicts of Interest Policy

•	Policy on Confidential Information

•	Policy on Inventions

•	Information Systems Security Policy

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(a)	Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b)	Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c)	Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d)	Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

(a)	All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

(b)	Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

(a)	Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b)	Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c)	Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d)	Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

(a)	All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

(b)	Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

(1)	The Quarterly Report on Form 10-Q of the Company for the quarter ended September 30, 2018 (the "Report") fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934 (15 U.S.C. 78m or 78o(d)); and

(2)	The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

(1)	The Quarterly Report on Form 10-Q of the Company for the quarter ended September 30, 2018 (the "Report") fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934 (15 U.S.C. 78m or 78o(d)); and

(2)	The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

•	Hood County Sand Plant - Hood County, TX (MSHA ID 41-04696);

•	Rawhide Sand Plant - Hood County, TX (MSHA ID 41-04777); and

•	Chippewa Falls Sand Plant - Chippewa County, WI (MSHA ID 47-03624).

v3.10.0.1

Document and Entity Information - shares	9 Months Ended
	Sep. 30, 2018	Oct. 26, 2018
Document and Entity Information [Abstract]
Entity Registrant Name	EOG RESOURCES INC
Entity Central Index Key	0000821189
Current Fiscal Year End Date	--12-31
Entity Filer Category	Large Accelerated Filer
Document Type	10-Q
Document Period End Date	Sep. 30, 2018
Document Fiscal Year Focus	2018
Document Fiscal Period Focus	Q3
Amendment Flag	false
Entity Common Stock, Shares Outstanding		579,903,041
Entity Emerging Growth Company	false
Entity Small Business	false

v3.10.0.1

Consolidated Statements of Income and Comprehensive Income - USD ($) shares in Thousands, $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Operating Revenues and Other
Total	$ 4,781,624	$ 2,644,844	$ 12,700,863	$ 7,867,881
Operating Expenses
Lease and Well	321,568	251,943	936,236	762,906
Transportation Costs	196,027	183,565	550,781	548,635
Gathering and Processing Costs	114,063	32,590	324,577	105,480
Exploration Costs	32,823	30,796	115,137	122,401
Dry Hole Costs	358	50	5,260	77
Impairments	44,617	53,677	160,934	325,798
Marketing Costs	1,326,974	793,536	3,853,827	2,320,671
Depreciation, Depletion and Amortization	918,180	846,222	2,515,445	2,527,642
General and Administrative	111,284	111,717	310,065	317,462
Taxes Other Than Income	209,043	125,912	582,395	386,319
Total	3,274,937	2,430,008	9,354,657	7,417,391
Operating Income	1,506,687	214,836	3,346,206	450,490
Other Income (Expense), Net	3,308	226	(4,516)	8,349
Income Before Interest Expense and Income Taxes	1,509,995	215,062	3,341,690	458,839
Interest Expense
Interest Expense, Net	63,632	69,082	189,032	211,010
Income Before Income Taxes	1,446,363	145,980	3,152,658	247,829
Income Tax Provision	255,411	45,439	626,386	95,718
Net Income	$ 1,190,952	$ 100,541	$ 2,526,272	$ 152,111
Net Income Per Share
Basic	$ 2.06	$ 0.17	$ 4.38	$ 0.26
Diluted	2.05	0.17	4.35	0.26
Dividends Declared per Common Share	$ 0.2200	$ 0.1675	$ 0.5900	$ 0.5025
Average Number of Common Shares
Basic	577,254	574,783	576,431	574,370
Diluted	581,559	578,736	580,442	578,453
Other Comprehensive Income (Loss)
Foreign Currency Translation Adjustments	$ (1,952)	$ 355	$ (179)	$ 1,924
Other, Net of Tax	6	(25)	18	(74)
Other Comprehensive Income (Loss)	(1,946)	330	(161)	1,850
Comprehensive Income	1,189,006	100,871	2,526,111	153,961
Crude Oil and Condensate
Operating Revenues and Other
Revenues	2,655,278	1,451,410	7,134,114	4,326,925
Natural Gas Liquids
Operating Revenues and Other
Revenues	353,704	180,038	861,473	480,389
Natural Gas
Operating Revenues and Other
Revenues	311,713	220,402	912,324	675,012
Gains (Losses) on Mark-to-Market Commodity Derivative Contracts
Operating Revenues and Other
Revenues	(52,081)	(6,606)	(297,735)	64,860
Gathering, Processing and Marketing
Operating Revenues and Other
Revenues	1,360,992	784,368	3,899,250	2,289,702
Gains (Losses) on Asset Dispositions, Net
Operating Revenues and Other
Revenues	115,944	(8,202)	94,658	(33,876)
Other, Net
Operating Revenues and Other
Revenues	$ 36,074	$ 23,434	$ 96,779	$ 64,869

v3.10.0.1

Consolidated Balance Sheets - USD ($) $ in Thousands	Sep. 30, 2018	Dec. 31, 2017
Current Assets
Cash and Cash Equivalents	$ 1,274,132	$ 834,228
Accounts Receivable, Net	2,151,247	1,597,494
Inventories	766,964	483,865
Assets from Price Risk Management Activities	1,569	7,699
Income Taxes Receivable	320,938	113,357
Other	302,242	242,465
Total	4,817,092	3,279,108
Property, Plant and Equipment
Oil and Gas Properties (Successful Efforts Method)	56,799,237	52,555,741
Other Property, Plant and Equipment	4,191,958	3,960,759
Total Property, Plant and Equipment	60,991,195	56,516,500
Less: Accumulated Depreciation, Depletion and Amortization	(33,043,454)	(30,851,463)
Total Property, Plant and Equipment, Net	27,947,741	25,665,037
Deferred Income Taxes	16,880	17,506
Other Assets	856,023	871,427
Total Assets	33,637,736	29,833,078
Current Liabilities
Accounts Payable	2,435,773	1,847,131
Accrued Taxes Payable	249,234	148,874
Dividends Payable	126,829	96,410
Liabilities from Price Risk Management Activities	132,618	50,429
Current Portion of Long-Term Debt	1,262,874	356,235
Other	217,819	226,463
Total	4,425,147	2,725,542
Long-Term Debt	5,171,949	6,030,836
Other Liabilities	1,302,249	1,275,213
Deferred Income Taxes	4,199,921	3,518,214
Commitments and Contingencies (Note 8)
Stockholders' Equity
Common Stock, $0.01 Par, 1,280,000,000 Shares Authorized and 580,308,937 Shares Issued at September 30, 2018 and 578,827,768 Shares Issued at December 31, 2017	205,803	205,788
Additional Paid in Capital	5,626,259	5,536,547
Accumulated Other Comprehensive Loss	(19,458)	(19,297)
Retained Earnings	12,778,104	10,593,533
Common Stock Held in Treasury, 478,042 Shares at September 30, 2018 and 350,961 Shares at December 31, 2017	(52,238)	(33,298)
Total Stockholders' Equity	18,538,470	16,283,273
Total Liabilities and Stockholders' Equity	$ 33,637,736	$ 29,833,078

v3.10.0.1

Consolidated Balance Sheets (Parenthetical) - $ / shares	Sep. 30, 2018	Dec. 31, 2017
Common Stock
Common Stock, Par Value (in dollars per share)	$ 0.01	$ 0.01
Common Stock, Shares Authorized (in shares)	1,280,000,000	1,280,000,000
Common Stock, Shares Issued (in shares)	580,308,937	578,827,768
Treasury Stock (in shares)
Common Stock Held in Treasury, Shares	478,042	350,961

v3.10.0.1

Consolidated Statements of Cash Flows - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017
Cash Flows from Operating Activities
Net Income	$ 2,526,272	$ 152,111
Items Not Requiring (Providing) Cash
Depreciation, Depletion and Amortization	2,515,445	2,527,642
Impairments	160,934	325,798
Stock-Based Compensation Expenses	116,290	101,537
Deferred Income Taxes	681,702	114,850
Gains (Losses) on Asset Dispositions, Net	94,658	(33,876)
Other, Net	15,314	(4,514)
Dry Hole Costs	5,260	77
Mark-to-Market Commodity Derivative Contracts
Total (Gains) Losses	297,735	(64,860)
Net Cash Received from (Payments for) Settlements of Commodity Derivative Contracts	(180,228)	4,730
Other, Net	1,652	270
Changes in Components of Working Capital and Other Assets and Liabilities
Accounts Receivable	(553,529)	(25,445)
Inventories	(286,817)	(17,674)
Accounts Payable	537,525	112,894
Accrued Taxes Payable	(36,891)	(49,967)
Other Assets	(103,334)	(83,940)
Other Liabilities	(14,776)	(69,224)
Changes in Components of Working Capital Associated with Investing and Financing Activities	95,484	(120,373)
Net Cash Provided by Operating Activities	5,683,380	2,937,788
Investing Cash Flows
Additions to Oil and Gas Properties	(4,571,932)	(2,927,988)
Additions to Other Property, Plant and Equipment	(202,384)	(139,558)
Proceeds from Sales of Assets	11,582	191,593
Other Investing Activities	(19,993)	0
Changes in Components of Working Capital Associated with Investing Activities	(95,541)	120,469
Net Cash Used in Investing Activities	(4,878,268)	(2,755,484)
Financing Cash Flows
Long-term Debt Repayments	0	(600,000)
Dividends Paid	(311,075)	(289,261)
Treasury Stock Purchased	(58,558)	(50,374)
Proceeds from Stock Options Exercised and Employee Stock Purchase Plan	12,098	11,174
Repayment of Capital Lease Obligation	(5,052)	(4,897)
Changes in Components of Working Capital Associated with Financing Activities	57	(96)
Net Cash Used in Financing Activities	(362,530)	(933,454)
Effect of Exchange Rate Changes on Cash	(2,678)	(2,607)
Increase (Decrease) in Cash and Cash Equivalents	439,904	(753,757)
Cash and Cash Equivalents at Beginning of Period	834,228	1,599,895
Cash and Cash Equivalents at End of Period	$ 1,274,132	$ 846,138

v3.10.0.1

Summary of Significant Accounting Policies (Notes)	9 Months Ended
	Sep. 30, 2018
Accounting Policies [Abstract]
Summary of Significant Accounting Policies	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, 2017, filed on February 27, 2018 (EOG's 2017 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, 2018, are not necessarily indicative of the results to be expected for the full year. Effective January 1, 2018, EOG adopted the provisions of Accounting Standards Update (ASU) 2014-09, "Revenue From Contracts With Customers" (ASU 2014-09). ASU 2014-09 and other related ASUs require entities to recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services. EOG elected to adopt ASU 2014-09 using the modified retrospective approach, which required EOG to recognize in retained earnings the cumulative effect at the date of adoption for all existing contracts with customers which were not substantially complete as of January 1, 2018. There was no impact to retained earnings upon adoption of ASU 2014-09. EOG presents disaggregated revenues by type of commodity within its Condensed Consolidated Statements of Income and Comprehensive Income and by geographic areas defined as operating segments. See Note 5. In connection with the adoption of ASU 2014-09, EOG presents natural gas processing fees relating to certain processing and marketing agreements within its United States segment as Gathering and Processing Costs, instead of as a deduction to Revenues within its Condensed Consolidated Statements of Income and Comprehensive Income. There was no impact to operating income, net income or cash flows resulting from changes to the presentation of natural gas processing fees. The impacts of the adoption of ASU 2014-09 for the three and nine months ended September 30, 2018, were as follows (in thousands):   Three Months Ended   September 30, 2018   Nine Months Ended   September 30, 2018   As Reported   Amounts Without Adoption of ASU 2014-09   Effect of Change   As Reported   Amounts Without Adoption of ASU 2014-09   Effect of Change Operating Revenues and Other                       Crude Oil and Condensate $ 2,655,278   $ 2,655,278   $ —   $ 7,134,114   $ 7,134,114   $ — Natural Gas Liquids 353,704   352,084   1,620   861,473   856,628   4,845 Natural Gas 311,713   256,169   55,544   912,324   770,441   141,883 Gathering, Processing and Marketing 1,360,992   1,355,909   5,083   3,899,250   3,883,222   16,028 Total Operating Revenues and Other 4,781,624   4,719,377   62,247   12,700,863   12,538,107   162,756 Operating Expenses                       Gathering and Processing Costs 114,063   56,899   57,164   324,577   177,849   146,728 Marketing Costs 1,326,974   1,321,891   5,083   3,853,827   3,837,799   16,028 Total Operating Expenses 3,274,937   3,212,690   62,247   9,354,657   9,191,901   162,756 Operating Income 1,506,687   1,506,687   —   3,346,206   3,346,206   — Revenues are recognized for the sale of crude oil and condensate, natural gas liquids (NGLs) and natural gas at the point control of the product is transferred to the customer, typically when production is delivered and title or risk of loss transfers to the customer. Arrangements for such sales are evidenced by signed contracts with prices typically based on stated market indices, with certain adjustments for product quality and geographic location. As EOG typically invoices customers shortly after performance obligations have been fulfilled, contract assets and contract liabilities are not recognized. The balances of accounts receivable from contracts with customers on January 1, 2018 and September 30, 2018, were $1,343 million and $1,812 million, respectively, and are included in Accounts Receivable, Net on the Condensed Consolidated Balance Sheets. Losses incurred on receivables from contracts with customers are infrequent and have been immaterial. Crude Oil and Condensate. EOG sells its crude oil and condensate production at the wellhead or further downstream at a contractually-specified delivery point. Revenue is recognized when control transfers to the customer based on contract terms which reflect prevailing market prices. Any costs incurred prior to the transfer of control, such as gathering and transportation, are recognized as Operating Expenses. Natural Gas Liquids. EOG delivers certain of its natural gas production to either EOG-owned processing facilities or third-party processing facilities, where extraction of NGLs occurs. For EOG-owned facilities, revenue is recognized after processing upon transfer of NGLs to a customer. For third-party facilities, extracted NGLs are sold to the owner of the processing facility at the tailgate, or EOG takes possession and sells the extracted NGLs at the tailgate or exercises its option to sell further downstream to various customers. Under typical arrangements for third-party facilities, revenue is recognized after processing upon the transfer of control of the NGLs, either at the tailgate of the processing plant or further downstream. EOG recognizes revenues based on contract terms which reflect prevailing market prices, with processing fees recognized as Gathering and Processing Costs. Natural Gas. EOG sells its natural gas production either at the wellhead or further downstream at a contractually-specified delivery point. In connection with the extraction of NGLs, EOG sells residue gas under separate agreements. Typically, EOG takes possession of the natural gas at the tailgate of the processing facility and sells it at the tailgate or further downstream. In each case, EOG recognizes revenues when control transfers to the customer, based on contract terms which reflect prevailing market prices. Gathering, Processing and Marketing. Gathering, processing and marketing revenues represent sales of third-party crude oil and condensate, NGLs and natural gas, as well as fees associated with gathering and processing third-party natural gas and revenues from sales of EOG-owned sand. EOG evaluates whether it is the principal or agent under these transactions. As control of the underlying commodity is transferred to EOG prior to the gathering, processing and marketing activities, EOG considers itself the principal of these arrangements. Accordingly, EOG recognizes these transactions on a gross basis. Purchases of third-party commodities are recorded as Marketing Costs, with sales of third-party commodities and fees received for gathering and processing recorded as Gathering, Processing and Marketing revenues. Recently Issued Accounting Standards. In March 2018, the Financial Accounting Standards Board (FASB) issued ASU 2018-05, "Income Taxes (Topic 740) - Amendments to SEC Paragraphs Pursuant to SEC Staff Accounting Bulletin No. 118" (ASU 2018-05). In December 2017, the United States (U.S.) enacted the Tax Cuts and Jobs Act (TCJA), which made significant changes to U.S. federal income tax law. Shortly after enactment of the TCJA, the SEC staff issued Staff Accounting Bulletin No. 118 (SAB 118), which provides guidance on accounting for the impact of the TCJA. ASU 2018-05 codified various paragraphs of SAB 118 and was effective upon issuance. Under SAB 118, an entity would use a similar approach as the measurement period provided in the Business Combinations Topic of the Accounting Standards Codification (ASC). An entity will recognize those matters for which the accounting can be completed. For matters that have not been completed, the entity would either (1) recognize provisional amounts to the extent that they are reasonably able to be estimated and adjust them over time as more information becomes available or (2) for any specific income tax effects of the TCJA for which a reasonable estimate cannot be determined, continue to apply the Income Taxes Topic of the ASC on the basis of the provisions of the tax laws that were in effect immediately before the TCJA was signed into law. EOG has prepared its condensed consolidated financial statements for the three and nine months ended September 30, 2018 in accordance with ASU 2018-05. As discussed in EOG’s 2017 Annual Report, provisional amounts were recorded for tax accruals of certain aspects of the TCJA. EOG has updated and finalized the 2017 U.S. federal provisional amounts. The 2017 state provisional amounts will be finalized in the fourth quarter of 2018. During the third quarter of 2018, EOG filed its consolidated 2017 U.S. federal income tax return, along with certain tax elections, and finalized its foreign earnings and profits study. The deemed repatriation tax decreased from the provisional amount of $179 million to $40 million mostly as a result of reducing the repatriation taxable income by net operating losses (NOLs), which had previously been expected to be utilized in future years. EOG is no longer electing to pay the repatriation tax in installments over eight years after considering recent Internal Revenue Service (IRS) guidance which indicated that no tax refunds would be issued until the entire repatriation tax liability is satisfied regardless of an installment election. EOG has reviewed the tax consequences of the repatriation tax on its outside basis differences in its investment in non-U.S. subsidiaries and has confirmed that no U.S. federal deferred tax liability is required at this time. EOG has analyzed the impact of the new "global intangible low-taxed income" (GILTI) inclusion and, while no taxable income inclusion is required in 2018, EOG may become subject to GILTI inclusion in future years and will treat any resulting tax as a period expense. The remeasurement of U.S. deferred tax assets and liabilities resulted in a provisional tax benefit of $2.2 billion in 2017, which was increased by approximately $52 million in the third quarter of 2018 due to the utilization of the aforementioned NOLs at the 2017 U.S. federal corporate income tax rate of 35% instead of the future tax rate of 21%. This additional tax benefit along with other less significant tax reform adjustments has lowered the 2018 year-to-date effective tax rate approximately two percentage points. EOG recorded a provisional amount in 2017 for its refundable alternative minimum tax (AMT) credits due to the lack of guidance, at that time, on whether any portion of these credits would be sequestered due to a federal budgetary provision. In the first quarter of 2018, the IRS affirmed that any refundable AMT credits resulting from the TCJA would be subject to sequestration. EOG does not expect further clarification from the IRS or Office of Management and Budget and therefore considers the accounting for sequestration on its refundable AMT credits complete. In February 2016, the FASB issued ASU 2016-02, "Leases (Topic 842)" (ASU 2016-02), which significantly changes accounting for leases by requiring that lessees recognize a right-of-use asset and a related lease liability representing the obligation to make lease payments, for certain lease transactions. Additional disclosures about an entity's lease transactions will also be required. ASU 2016-02 defines a lease as "a contract, or part of a contract, that conveys the right to control the use of identified property, plant or equipment (an identified asset) for a period of time in exchange for consideration." In January 2018, the FASB issued ASU 2018-01, "Leases (Topic 842) - Land Easement Practical Expedient for Transition to Topic 842" (ASU 2018-01), which permits an entity an optional election to not evaluate under ASU 2016-02 those existing or expired land easements that were not previously accounted for as leases prior to the adoption of ASU 2016-02. Additionally, in July 2018, the FASB issued ASU 2018-11, “Leases (Topic 842) - Targeted Improvements” (ASU 2018-11), which permits an entity (i) to apply the provisions of ASU 2016-02 at the adoption date instead of the earliest period presented in the financial statements, and, as a lessor, (ii) to account for lease and nonlease components as a single component as the nonlease components would otherwise be accounted for under the provisions of ASU 2014-09. ASU 2016-02 and other related ASUs are effective for interim and annual periods beginning after December 31, 2018, and early application is permitted. Based on the provisions of ASU 2018-11 and other related ASUs, lessees and lessors may recognize and measure leases at the beginning of the earliest period presented in the financial statements, defined as the effective date, using a modified retrospective approach, or at the adoption date by recognizing a cumulative-effect adjustment to the opening balance of retained earnings. EOG is continuing its assessment of ASU 2016-02 by implementing its project plan, including a lease accounting software solution. EOG has assessed the scope of its current contractual arrangements, reviewed the majority of its existing contracts and is continuing to evaluate certain operational and corporate policies and processes in light of these findings. EOG enters into contracts for drilling rig services, fracturing services, compression, real estate and other contracts which contain equipment and other assets used in its exploration, development and production activities and corporate functions. Certain of these contracts are anticipated to require recognition of a right-of-use asset and related lease liability. At this time, the impact upon adoption of ASU 2016-02 and other related ASUs is not quantifiable, but is expected to significantly impact EOG’s consolidated balance sheet by increasing assets and liabilities related to operating leases. EOG plans to elect the practical expedient under ASU 2018-11 and apply the provisions of ASU 2016-02 on the adoption date, January 1, 2019. Additionally, EOG plans to elect 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, but does not plan to elect the practical expedient of hindsight when determining the lease term of existing contracts at the effective date. EOG also plans to elect the practical expedient under ASU 2018-01 and not evaluate existing or expired land easements not previously accounted for as leases prior to the effective date.

v3.10.0.1

Stock-Based Compensation (Notes)	9 Months Ended
	Sep. 30, 2018
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
Stock-Based Compensation	Stock-Based Compensation As more fully discussed in Note 7 to the Consolidated Financial Statements included in EOG's 2017 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,   2018   2017   2018   2017 Lease and Well $ 12.9   $ 9.5   $ 37.1   $ 30.0 Gathering and Processing Costs 0.1   0.1   0.3   0.5 Exploration Costs 5.8   4.7   18.4   16.1 General and Administrative 30.2   29.2   60.5   54.9 Total $ 49.0   $ 43.5   $ 116.3   $ 101.5 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 performance stock and other stock-based awards. At September 30, 2018, approximately 13.7 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 $21.7 million and $20.9 million during the three months ended September 30, 2018 and 2017, respectively, and $45.4 million and $42.9 million during the nine months ended September 30, 2018 and 2017, respectively. Weighted average fair values and valuation assumptions used to value stock option, SAR and ESPP grants during the nine-month periods ended September 30, 2018 and 2017 are as follows:   Stock Options/SARs   ESPP   Nine Months Ended   September 30,   Nine Months Ended   September 30,   2018   2017   2018   2017 Weighted Average Fair Value of Grants $ 33.49   $ 23.94   $ 25.52   $ 22.10 Expected Volatility 28.22 %   28.28 %   24.36 %   26.96 % Risk-Free Interest Rate 2.68 %   1.52 %   1.86 %   0.89 % Dividend Yield 0.72 %   0.75 %   0.64 %   0.71 % Expected Life 5.0 years   5.1 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. The following table sets forth stock option and SAR transactions for the nine-month periods ended September 30, 2018 and 2017 (stock options and SARs in thousands):   Nine Months Ended   September 30, 2018   Nine Months Ended   September 30, 2017   Number of Stock Options/SARs   Weighted Average Grant Price   Number of Stock Options/SARs   Weighted Average Grant Price Outstanding at January 1 9,103   $ 83.89   9,850   $ 75.53 Granted 1,884   126.65   2,260   96.24 Exercised (1) (2,144 )   69.62   (1,674 )   55.63 Forfeited (167 )   91.89   (269 )   90.22 Outstanding at September 30 (2) 8,676   $ 96.55   10,167   $ 83.02 Vested or Expected to Vest (3) 8,316   $ 96.08   9,799   $ 82.69 Exercisable at September 30 (4) 4,202   $ 85.80   5,517   $ 75.59 (1) The total intrinsic value of stock options/SARs exercised for the nine months ended September 30, 2018 and 2017 was $103.7 million and $66.6 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, 2018 and 2017 was $269.1 million and $147.8 million, respectively. At September 30, 2018 and 2017, the weighted average remaining contractual life was 4.8 years and 4.3 years, respectively. (3) The total intrinsic value of stock options/SARs vested or expected to vest at September 30, 2018 and 2017 was $261.9 million and $145.9 million, respectively. At September 30, 2018 and 2017, the weighted average remaining contractual life was 4.7 years and 4.3 years, respectively. (4) The total intrinsic value of stock options/SARs exercisable at September 30, 2018 and 2017 was $175.5 million and $123.2 million, respectively. At September 30, 2018 and 2017, the weighted average remaining contractual life was 3.4 years and 2.8 years, respectively. At September 30, 2018, unrecognized compensation expense related to non-vested stock option, SAR and ESPP grants totaled $119.7 million. Such unrecognized expense will be amortized on a straight-line basis over a weighted average period of 2.3 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 $17.5 million and $15.8 million for the three months ended September 30, 2018 and 2017, respectively, and $58.8 million and $50.0 million for the nine months ended September 30, 2018 and 2017, respectively. The following table sets forth restricted stock and restricted stock unit transactions for the nine-month periods ended September 30, 2018 and 2017 (shares and units in thousands):   Nine Months Ended   September 30, 2018   Nine Months Ended   September 30, 2017   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 3,905   $ 88.57   3,962   $ 79.63 Granted 792   117.67   1,061   97.26 Released (1) (708 )   77.46   (837 )   59.67 Forfeited (150 )   91.36   (190 )   84.66 Outstanding at September 30 (2) 3,839   $ 96.52   3,996   $ 88.25 (1) The total intrinsic value of restricted stock and restricted stock units released for the nine months ended September 30, 2018 and 2017 was $80.2 million and $81.6 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, 2018 and 2017 was $489.7 million and $386.6 million, respectively. At September 30, 2018, unrecognized compensation expense related to restricted stock and restricted stock units totaled $194.5 million. Such unrecognized expense will be amortized on a straight-line basis over a weighted average period of 2.2 years. Performance Units and Performance Stock. EOG has granted performance units and/or performance stock (collectively, Performance Awards) to its executive officers annually since 2012. As more fully discussed in the grant agreements, the performance metric applicable to the Performance Awards 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 Awards granted could be outstanding. The fair value of the Performance Awards is estimated using a Monte Carlo simulation. Stock-based compensation expense related to the Performance Award grants totaled $9.8 million and $6.8 million for the three-month periods ended September 30, 2018 and 2017, respectively, and $12.1 million and $8.6 million for the nine-month periods ended September 30, 2018 and 2017, respectively. The following table sets forth the Performance Awards transactions for the nine-month periods ended September 30, 2018 and 2017 (units in thousands):   Nine Months Ended   September 30, 2018   Nine Months Ended   September 30, 2017   Number of Units   Weighted Average Price per Grant Date   Number of Units   Weighted Average Price per Grant Date Outstanding at January 1 502   $ 90.96   545   $ 80.92 Granted 107   127.00   78   96.29 Granted for Performance Multiple (1) 72   101.87   119   84.43 Released (2) (148 )   84.43   (240 )   66.69 Forfeited —   —   —   — Outstanding at September 30 (3) 533 (4) $ 101.50   502   $ 90.96 (1) Upon completion of the Performance Period for the Performance Awards granted in 2014 and 2013, a performance multiple of 200% was applied to each of the grants resulting in additional grants of Performance Awards in February 2018 and February 2017, respectively. (2) The total intrinsic value of Performance Awards released during the nine months ended September 30, 2018 and 2017 was approximately $17.7 million and $23.6 million, respectively. The intrinsic value is based upon the closing price of EOG's common stock on the date the Performance Awards are released. (3) The total intrinsic value of Performance Awards outstanding at September 30, 2018 and 2017 was approximately $68.0 million and $48.6 million, respectively. (4) Upon the application of the relevant performance multiple at the completion of each of the remaining Performance Periods, a minimum of 143,610 and a maximum of 921,940 Performance Awards could be outstanding. At September 30, 2018, unrecognized compensation expense related to Performance Awards totaled $11.0 million. Such unrecognized expense will be amortized on a straight-line basis over a weighted average period of 1.7 years.

v3.10.0.1

Net Income Per Share (Notes)	9 Months Ended
	Sep. 30, 2018
Earnings Per Share [Abstract]
Net Income Per Share	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, 2018 and 2017 (in thousands, except per share data):   Three Months Ended   September 30,   Nine Months Ended   September 30,   2018   2017   2018   2017 Numerator for Basic and Diluted Earnings Per Share -               Net Income $ 1,190,952   $ 100,541   $ 2,526,272   $ 152,111 Denominator for Basic Earnings Per Share -               Weighted Average Shares 577,254   574,783   576,431   574,370 Potential Dilutive Common Shares -               Stock Options/SARs 1,432   1,451   1,317   1,518 Restricted Stock/Units and Performance Units/Stock 2,873   2,502   2,694   2,565 Denominator for Diluted Earnings Per Share -               Adjusted Diluted Weighted Average Shares 581,559   578,736   580,442   578,453 Net Income Per Share               Basic $ 2.06   $ 0.17   $ 4.38   $ 0.26 Diluted $ 2.05   $ 0.17   $ 4.35   $ 0.26 The diluted earnings per share calculation excludes stock options and SARs that were anti-dilutive. Shares underlying the excluded stock options and SARs were 0.5 million and 4.2 million shares for the three months ended September 30, 2018 and 2017, respectively, and were 0.2 million and 3.6 million shares, respectively, for the nine months ended September 30, 2018 and 2017, respectively.

v3.10.0.1

Supplemental Cash Flow Information (Notes)	9 Months Ended
	Sep. 30, 2018
Supplemental Cash Flow Information [Abstract]
Supplemental Cash Flow Information	Supplemental Cash Flow Information Net cash paid for interest and income taxes was as follows for the nine-month periods ended September 30, 2018 and 2017 (in thousands):   Nine Months Ended   September 30,   2018   2017 Interest (1) $ 172,076   $ 202,320 Income Taxes, Net of Refunds Received $ 81,059   $ 92,391 (1) Net of capitalized interest of $18 million and $21 million for the nine months ended September 30, 2018 and 2017, respectively. EOG's accrued capital expenditures at September 30, 2018 and 2017 were $702 million and $545 million, respectively. Non-cash investing activities for the nine months ended September 30, 2018, included additions of $222 million to EOG's oil and gas properties as a result of property exchanges and an addition of $49 million to EOG's other property, plant and equipment primarily in connection with a capital lease transaction in the Permian Basin. Non-cash investing activities for the nine months ended September 30, 2017, included additions of $214 million to EOG's oil and gas properties as a result of property exchanges.

v3.10.0.1

Segment Information (Notes)	9 Months Ended
	Sep. 30, 2018
Segment Reporting [Abstract]
Segment Information	Segment Information Selected financial information by reportable segment is presented below for the three-month and nine-month periods ended September 30, 2018 and 2017 (in thousands):   Three Months Ended   September 30,   Nine Months Ended   September 30,   2018   2017   2018   2017 Operating Revenues and Other               United States $ 4,653,342   $ 2,569,867   $ 12,339,086   $ 7,620,601 Trinidad 84,648   63,800   247,272   210,022 Other International (1) 43,634   11,177   114,505   37,258 Total $ 4,781,624   $ 2,644,844   $ 12,700,863   $ 7,867,881 Operating Income (Loss)               United States $ 1,458,641   $ 207,173   $ 3,251,377   $ 457,018 Trinidad 48,988   21,739   117,106   70,512 Other International (1) (942 )   (14,076 )   (22,277 )   (77,040 ) Total 1,506,687   214,836   3,346,206   450,490 Reconciling Items               Other Income (Expense), Net 3,308   226   (4,516 )   8,349 Interest Expense, Net (63,632 )   (69,082 )   (189,032 )   (211,010 ) Income Before Income Taxes $ 1,446,363   $ 145,980   $ 3,152,658   $ 247,829 (1) Other International primarily consists of EOG's United Kingdom, China and Canada operations. Total assets by reportable segment are presented below at September 30, 2018 and December 31, 2017 (in thousands):   At September 30, 2018   At December 31, 2017 Total Assets       United States $ 32,656,676   $ 28,312,599 Trinidad 619,127   974,477 Other International (1) 361,933   546,002 Total $ 33,637,736   $ 29,833,078 (1) Other International primarily consists of EOG's United Kingdom, China and Canada operations.

v3.10.0.1

Asset Retirement Obligations (Notes)	9 Months Ended
	Sep. 30, 2018
Asset Retirement Obligation [Abstract]
Asset Retirement Obligations	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 periods ended September 30, 2018 and 2017 (in thousands):   Nine Months Ended   September 30,   2018   2017 Carrying Amount at January 1 $ 946,848   $ 912,926 Liabilities Incurred 63,443   30,114 Liabilities Settled (1) (15,319 )   (53,638 ) Accretion 27,306   25,963 Revisions (39,137 )   (1,791 ) Foreign Currency Translations (2,197 )   16,902 Carrying Amount at September 30 $ 980,944   $ 930,476         Current Portion $ 18,209   $ 23,606 Noncurrent Portion $ 962,735   $ 906,870 (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.

v3.10.0.1

Exploratory Well Costs (Notes)	9 Months Ended
	Sep. 30, 2018
Capitalized Exploratory Well Costs [Abstract]
Exploratory Well Costs	Exploratory Well Costs EOG's net changes in capitalized exploratory well costs for the nine-month period ended September 30, 2018, are presented below (in thousands):   Nine Months Ended   September 30, 2018 Balance at January 1 $ 2,167 Additions Pending the Determination of Proved Reserves 6,497 Reclassifications to Proved Properties (5,346 ) Costs Charged to Expense (433 ) Balance at September 30 $ 2,885 At September 30, 2018, all capitalized exploratory well costs had been capitalized for periods of less than one year.

v3.10.0.1

Commitments and Contingencies (Notes)	9 Months Ended
	Sep. 30, 2018
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	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.

v3.10.0.1

Pension and Postretirement Benefits (Notes)	9 Months Ended
	Sep. 30, 2018
Retirement Benefits [Abstract]
Pension and Postretirement Benefits	Pension and Postretirement Benefits EOG has defined contribution pension plans in place for most of its employees in the United States, Trinidad and the United Kingdom, and a defined benefit pension plan covering certain of its employees in Trinidad. For the nine months ended September 30, 2018 and 2017, EOG's total costs recognized for these pension plans were $30 million and $27 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.

v3.10.0.1

Long-Term Debt and Common Stock (Notes)	9 Months Ended
	Sep. 30, 2018
Debt Disclosure [Abstract]
Long-Term Debt and Common Stock	Long-Term Debt and Common Stock Long-Term Debt. During the nine months ended September 30, 2018 and 2017, EOG utilized commercial paper borrowings, bearing market interest rates, for various corporate financing purposes. At September 30, 2018 and December 31, 2017, EOG had no outstanding commercial paper borrowings or uncommitted credit facility borrowings. The average borrowings outstanding under the commercial paper program were $11 million and $9 million during the nine months ended September 30, 2018 and 2017, respectively. The weighted average interest rate for commercial paper borrowings during the nine months ended September 30, 2018 and 2017, was 1.97% and 1.39%, respectively. On October 1, 2018, EOG repaid upon maturity the $350 million aggregate principal amount of its 6.875% Senior Notes due 2018. EOG currently has a $2.0 billion senior unsecured Revolving Credit Agreement (Agreement) with domestic and foreign lenders. The Agreement has a scheduled maturity date of July 21, 2020, 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. Advances under the Agreement will accrue interest based, at EOG's option, on either the London InterBank Offered Rate plus an applicable margin (Eurodollar rate) or the base rate (as defined in the Agreement) plus an applicable margin. At September 30, 2018 and December 31, 2017, there were no borrowings or letters of credit outstanding under the Agreement. The Eurodollar rate and applicable base rate, had there been any amounts borrowed under the Agreement at September 30, 2018, would have been 3.16% and 5.25%, respectively. Common Stock. On August 2, 2018, EOG's Board of Directors increased the quarterly cash dividend on the common stock from the previous $0.1850 per share to $0.22 per share, effective beginning with the dividend to be paid on October 31, 2018, to stockholders of record as of October 17, 2018.

v3.10.0.1

Fair Value Measurements (Notes)	9 Months Ended
	Sep. 30, 2018
Fair Value Disclosures [Abstract]
Fair Value Measurements	Fair Value Measurements As more fully discussed in Note 13 to the Consolidated Financial Statements included in EOG's 2017 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, 2018 and December 31, 2017 (in millions):   Fair Value Measurements Using:   Quoted Prices in Active Markets (Level 1)   Significant Other Observable Inputs (Level 2)   Significant Unobservable Inputs (Level 3)   Total At September 30, 2018               Financial Assets:               Crude Oil Basis Swaps $ —   $ 35   $ —   $ 35 Financial Liabilities:               Crude Oil Swaps $ —   $ 159   $ —   $ 159 Crude Oil Basis Swaps —   2   —   2                 At December 31, 2017               Financial Assets:               Natural Gas Swaps $ —   $ 2   $ —   $ 2 Natural Gas Options/Collars —   6   —   6 Financial Liabilities:               Crude Oil Swaps $ —   $ 38   $ —   $ 38 Crude Oil Basis Swaps —   19   —   19 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. 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 oil and gas properties and other assets with a carrying amount of $165 million were written down to their fair value of $131 million, resulting in pretax impairment charges of $34 million for the nine months ended September 30, 2018. Included in the $34 million pretax impairment charges are $21 million for a commodity price-related write-down of other assets. EOG utilized average prices per acre from comparable market transactions and estimated discounted cash flows as the basis for determining the fair value of unproved and proved properties, respectively, received in non-cash property exchanges. See Note 4. Fair Value of Debt. At September 30, 2018 and December 31, 2017, EOG had outstanding $6,390 million aggregate principal amount of senior notes, which had estimated fair values at such dates of approximately $6,400 million and $6,602 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.

v3.10.0.1

Risk Management Activities (Notes)	9 Months Ended
	Sep. 30, 2018
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Risk Management Activities	Risk Management Activities Commodity Price Risk. As more fully discussed in Note 12 to the Consolidated Financial Statements included in EOG's 2017 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 and natural gas. EOG utilizes financial commodity derivative instruments, primarily price swap, option, swaption, collar and basis swap contracts, as a means to manage this price risk. EOG has not designated any of its financial commodity derivative contracts as accounting hedges and, accordingly, accounts for financial commodity derivative contracts using the mark-to-market accounting method. Commodity Derivative Contracts. Prices received by EOG for its crude oil production generally vary from U.S. New York Mercantile Exchange (NYMEX) West Texas Intermediate 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 pricing in Midland, Texas, and Cushing, Oklahoma (Midland Differential). Presented below is a comprehensive summary of EOG's Midland Differential basis swap contracts for the nine months ended September 30, 2018. The weighted average price differential expressed in dollars per barrel ($/Bbl) represents the amount of reduction to Cushing, Oklahoma, prices for the notional volumes expressed in barrels per day (Bbld) covered by the basis swap contracts.   Midland Differential Basis Swap Contracts       Volume (Bbld)   Weighted Average Price Differential ($/Bbl)       2018           January 1, 2018 through October 31, 2018 (closed)   15,000   $ 1.063   November 1, 2018 through December 31, 2018   15,000   1.063               2019           January 1, 2019 through December 31, 2019   20,000   $ 1.075 EOG has also entered into crude oil basis swap contracts in order to fix the differential between pricing in the U.S. Gulf Coast and Cushing, Oklahoma (Gulf Coast Differential). Presented below is a comprehensive summary of EOG's Gulf Coast Differential basis swap contracts for the nine months ended September 30, 2018. 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)       2018           January 1, 2018 through September 30, 2018 (closed)   37,000   $ 3.818   October 2018 (closed)   52,000   3.911   November 1, 2018 through December 31, 2018   52,000   3.911               2019           January 1, 2019 through December 31, 2019   10,000   $ 5.558 Presented below is a comprehensive summary of EOG's crude oil price swap contracts for the nine months ended September 30, 2018, with notional volumes expressed in Bbld and prices expressed in $/Bbl. Crude Oil Price Swap Contracts     Volume (Bbld)   Weighted Average Price ($/Bbl) 2018         January 1, 2018 through September 30, 2018 (closed)   134,000   $ 60.04 October 1, 2018 through December 31, 2018   134,000   60.04 Presented below is a comprehensive summary of EOG's natural gas price swap contracts for the nine months ended September 30, 2018, 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) 2018         March 1, 2018 through October 31, 2018 (closed)   35,000   $ 3.00 November 2018   35,000   3.00 EOG has sold call options which establish a ceiling price for the sale of notional volumes of natural gas as specified in the call option contracts. The call options require that EOG pay the difference between the call option strike price and either the average or last business day 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 call option strike price. In addition, EOG has purchased put options which establish a floor price for the sale of notional volumes of natural gas as specified in the put option contracts. The put options grant EOG the right to receive the difference between the put option strike price and the Henry Hub Index Price in the event the Henry Hub Index Price is below the put option strike price. Presented below is a comprehensive summary of EOG's natural gas call and put option contracts for the nine months ended September 30, 2018, with notional volumes expressed in MMBtud and prices expressed in $/MMBtu. Natural Gas Option Contracts   Call Options Sold   Put Options Purchased   Volume (MMBtud)   Weighted Average Price ($/MMBtu)   Volume (MMBtud)   Weighted Average Price ($/MMBtu) 2018               March 1, 2018 through October 31, 2018 (closed) 120,000   $ 3.38   96,000   $ 2.94 November 2018 120,000   3.38   96,000   2.94 The following table sets forth the amounts and classification of EOG's outstanding financial derivative instruments at September 30, 2018 and December 31, 2017.  Certain amounts may be presented on a net basis on the Condensed Consolidated Financial Statements when such amounts are with the same counterparty and subject to a master netting arrangement (in millions):          Fair Value at Description   Location on Balance Sheet   September 30, 2018   December 31, 2017 Asset Derivatives             Crude oil and natural gas derivative contracts -             Current portion   Assets from Price Risk Management Activities   $ 2   $ 8 Noncurrent portion   Other Assets   5   — Liability Derivatives             Crude oil and natural gas derivative contracts -             Current portion   Liabilities from Price Risk Management Activities (1)   $ 133   $ 50 Noncurrent portion   Other Liabilities   —   7 (1) The current portion of Liabilities from Price Risk Management Activities consists of gross liabilities of $161 million, partially offset by gross assets of $28 million at September 30, 2018, and gross liabilities of $55 million, partially offset by gross assets of $5 million at December 31, 2017. 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 those arising from physical and financial transactions. In some instances, EOG renegotiates payment terms and/or requires collateral, parent guarantees or letters of credit to minimize credit risk. All of EOG's derivative instruments are covered by International Swap Dealers Association Master Agreements (ISDAs) with counterparties. The ISDAs may contain provisions that require EOG, if it is the party in a net liability position, to post collateral when the amount of the net liability exceeds the threshold level specified for EOG's then-current credit ratings. In addition, the ISDAs may also provide that as a result of certain circumstances, including certain events that cause EOG's credit ratings to become materially weaker than its then-current ratings, the counterparty may require all outstanding derivatives under the ISDAs to be settled immediately. See Note 11 for the aggregate fair value of all derivative instruments that were in a net liability position at September 30, 2018 and December 31, 2017. EOG had no collateral posted and held no collateral at September 30, 2018 and December 31, 2017.

v3.10.0.1

Acquisitions and Divestitures (Notes)	9 Months Ended
	Sep. 30, 2018
Discontinued Operations and Disposal Groups [Abstract]
Acquisitions and Divestitures	Acquisitions and Divestitures During the nine months ended September 30, 2018, EOG recognized a net gain on asset dispositions of $95 million, primarily due to non-cash property exchanges in Texas, New Mexico and Wyoming and received proceeds of approximately $12 million. Additionally, in the third quarter of 2018, EOG's wholly-owned subsidiary signed a share purchase and sale agreement for the sale of all of its interest in EOG Resources United Kingdom Limited, which is expected to close in the fourth quarter of 2018. At September 30, 2018, the book value of the assets held for sale and the related liabilities were $235 million and $65 million, respectively. During the nine months ended September 30, 2017, EOG recognized a net loss on asset dispositions of $(34) million and received proceeds of approximately $192 million primarily from the sale of producing assets, unproved leasehold and other property, plant and equipment in Oklahoma and Texas.

v3.10.0.1

Summary of Significant Accounting Policies (Tables)	9 Months Ended
	Sep. 30, 2018
Accounting Policies [Abstract]
Schedule of Impact of Adoption of New Revenue Recognition Standard (Tables)	The impacts of the adoption of ASU 2014-09 for the three and nine months ended September 30, 2018, were as follows (in thousands):   Three Months Ended   September 30, 2018   Nine Months Ended   September 30, 2018   As Reported   Amounts Without Adoption of ASU 2014-09   Effect of Change   As Reported   Amounts Without Adoption of ASU 2014-09   Effect of Change Operating Revenues and Other                       Crude Oil and Condensate $ 2,655,278   $ 2,655,278   $ —   $ 7,134,114   $ 7,134,114   $ — Natural Gas Liquids 353,704   352,084   1,620   861,473   856,628   4,845 Natural Gas 311,713   256,169   55,544   912,324   770,441   141,883 Gathering, Processing and Marketing 1,360,992   1,355,909   5,083   3,899,250   3,883,222   16,028 Total Operating Revenues and Other 4,781,624   4,719,377   62,247   12,700,863   12,538,107   162,756 Operating Expenses                       Gathering and Processing Costs 114,063   56,899   57,164   324,577   177,849   146,728 Marketing Costs 1,326,974   1,321,891   5,083   3,853,827   3,837,799   16,028 Total Operating Expenses 3,274,937   3,212,690   62,247   9,354,657   9,191,901   162,756 Operating Income 1,506,687   1,506,687   —   3,346,206   3,346,206   —

v3.10.0.1

Stock-Based Compensation (Tables)	9 Months Ended
	Sep. 30, 2018
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
Schedule of Employee Service Share-based Compensation, Allocation of Recognized Period Costs	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,   2018   2017   2018   2017 Lease and Well $ 12.9   $ 9.5   $ 37.1   $ 30.0 Gathering and Processing Costs 0.1   0.1   0.3   0.5 Exploration Costs 5.8   4.7   18.4   16.1 General and Administrative 30.2   29.2   60.5   54.9 Total $ 49.0   $ 43.5   $ 116.3   $ 101.5
Weighted Average Fair Values and Valuation Assumptions	Weighted average fair values and valuation assumptions used to value stock option, SAR and ESPP grants during the nine-month periods ended September 30, 2018 and 2017 are as follows:   Stock Options/SARs   ESPP   Nine Months Ended   September 30,   Nine Months Ended   September 30,   2018   2017   2018   2017 Weighted Average Fair Value of Grants $ 33.49   $ 23.94   $ 25.52   $ 22.10 Expected Volatility 28.22 %   28.28 %   24.36 %   26.96 % Risk-Free Interest Rate 2.68 %   1.52 %   1.86 %   0.89 % Dividend Yield 0.72 %   0.75 %   0.64 %   0.71 % Expected Life 5.0 years   5.1 years   0.5 years   0.5 years
Stock Options and SARs Transactions	The following table sets forth stock option and SAR transactions for the nine-month periods ended September 30, 2018 and 2017 (stock options and SARs in thousands):   Nine Months Ended   September 30, 2018   Nine Months Ended   September 30, 2017   Number of Stock Options/SARs   Weighted Average Grant Price   Number of Stock Options/SARs   Weighted Average Grant Price Outstanding at January 1 9,103   $ 83.89   9,850   $ 75.53 Granted 1,884   126.65   2,260   96.24 Exercised (1) (2,144 )   69.62   (1,674 )   55.63 Forfeited (167 )   91.89   (269 )   90.22 Outstanding at September 30 (2) 8,676   $ 96.55   10,167   $ 83.02 Vested or Expected to Vest (3) 8,316   $ 96.08   9,799   $ 82.69 Exercisable at September 30 (4) 4,202   $ 85.80   5,517   $ 75.59 (1) The total intrinsic value of stock options/SARs exercised for the nine months ended September 30, 2018 and 2017 was $103.7 million and $66.6 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, 2018 and 2017 was $269.1 million and $147.8 million, respectively. At September 30, 2018 and 2017, the weighted average remaining contractual life was 4.8 years and 4.3 years, respectively. (3) The total intrinsic value of stock options/SARs vested or expected to vest at September 30, 2018 and 2017 was $261.9 million and $145.9 million, respectively. At September 30, 2018 and 2017, the weighted average remaining contractual life was 4.7 years and 4.3 years, respectively. (4) The total intrinsic value of stock options/SARs exercisable at September 30, 2018 and 2017 was $175.5 million and $123.2 million, respectively. At September 30, 2018 and 2017, the weighted average remaining contractual life was 3.4 years and 2.8 years, respectively.
Restricted Stock and Restricted Stock Unit Transactions	The following table sets forth restricted stock and restricted stock unit transactions for the nine-month periods ended September 30, 2018 and 2017 (shares and units in thousands):   Nine Months Ended   September 30, 2018   Nine Months Ended   September 30, 2017   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 3,905   $ 88.57   3,962   $ 79.63 Granted 792   117.67   1,061   97.26 Released (1) (708 )   77.46   (837 )   59.67 Forfeited (150 )   91.36   (190 )   84.66 Outstanding at September 30 (2) 3,839   $ 96.52   3,996   $ 88.25 (1) The total intrinsic value of restricted stock and restricted stock units released for the nine months ended September 30, 2018 and 2017 was $80.2 million and $81.6 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, 2018 and 2017 was $489.7 million and $386.6 million, respectively.
Weighted Average Fair Values and Valuation Assumptions for Performance Award Grants	The following table sets forth the Performance Awards transactions for the nine-month periods ended September 30, 2018 and 2017 (units in thousands):   Nine Months Ended   September 30, 2018   Nine Months Ended   September 30, 2017   Number of Units   Weighted Average Price per Grant Date   Number of Units   Weighted Average Price per Grant Date Outstanding at January 1 502   $ 90.96   545   $ 80.92 Granted 107   127.00   78   96.29 Granted for Performance Multiple (1) 72   101.87   119   84.43 Released (2) (148 )   84.43   (240 )   66.69 Forfeited —   —   —   — Outstanding at September 30 (3) 533 (4) $ 101.50   502   $ 90.96 (1) Upon completion of the Performance Period for the Performance Awards granted in 2014 and 2013, a performance multiple of 200% was applied to each of the grants resulting in additional grants of Performance Awards in February 2018 and February 2017, respectively. (2) The total intrinsic value of Performance Awards released during the nine months ended September 30, 2018 and 2017 was approximately $17.7 million and $23.6 million, respectively. The intrinsic value is based upon the closing price of EOG's common stock on the date the Performance Awards are released. (3) The total intrinsic value of Performance Awards outstanding at September 30, 2018 and 2017 was approximately $68.0 million and $48.6 million, respectively. (4) Upon the application of the relevant performance multiple at the completion of each of the remaining Performance Periods, a minimum of 143,610 and a maximum of 921,940 Performance Awards could be outstanding.

v3.10.0.1

Net Income Per Share (Tables)	9 Months Ended
	Sep. 30, 2018
Earnings Per Share [Abstract]
Computation of 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, 2018 and 2017 (in thousands, except per share data):   Three Months Ended   September 30,   Nine Months Ended   September 30,   2018   2017   2018   2017 Numerator for Basic and Diluted Earnings Per Share -               Net Income $ 1,190,952   $ 100,541   $ 2,526,272   $ 152,111 Denominator for Basic Earnings Per Share -               Weighted Average Shares 577,254   574,783   576,431   574,370 Potential Dilutive Common Shares -               Stock Options/SARs 1,432   1,451   1,317   1,518 Restricted Stock/Units and Performance Units/Stock 2,873   2,502   2,694   2,565 Denominator for Diluted Earnings Per Share -               Adjusted Diluted Weighted Average Shares 581,559   578,736   580,442   578,453 Net Income Per Share               Basic $ 2.06   $ 0.17   $ 4.38   $ 0.26 Diluted $ 2.05   $ 0.17   $ 4.35   $ 0.26

v3.10.0.1

Supplemental Cash Flow Information (Tables)	9 Months Ended
	Sep. 30, 2018
Supplemental Cash Flow Information [Abstract]
Net Cash Paid For Interest and Income Taxes	Net cash paid for interest and income taxes was as follows for the nine-month periods ended September 30, 2018 and 2017 (in thousands):   Nine Months Ended   September 30,   2018   2017 Interest (1) $ 172,076   $ 202,320 Income Taxes, Net of Refunds Received $ 81,059   $ 92,391 (1) Net of capitalized interest of $18 million and $21 million for the nine months ended September 30, 2018 and 2017, respectively.

v3.10.0.1

Segment Information (Tables)	9 Months Ended
	Sep. 30, 2018
Segment Reporting [Abstract]
Selected Financial Information by Reportable Segment	Selected financial information by reportable segment is presented below for the three-month and nine-month periods ended September 30, 2018 and 2017 (in thousands):   Three Months Ended   September 30,   Nine Months Ended   September 30,   2018   2017   2018   2017 Operating Revenues and Other               United States $ 4,653,342   $ 2,569,867   $ 12,339,086   $ 7,620,601 Trinidad 84,648   63,800   247,272   210,022 Other International (1) 43,634   11,177   114,505   37,258 Total $ 4,781,624   $ 2,644,844   $ 12,700,863   $ 7,867,881 Operating Income (Loss)               United States $ 1,458,641   $ 207,173   $ 3,251,377   $ 457,018 Trinidad 48,988   21,739   117,106   70,512 Other International (1) (942 )   (14,076 )   (22,277 )   (77,040 ) Total 1,506,687   214,836   3,346,206   450,490 Reconciling Items               Other Income (Expense), Net 3,308   226   (4,516 )   8,349 Interest Expense, Net (63,632 )   (69,082 )   (189,032 )   (211,010 ) Income Before Income Taxes $ 1,446,363   $ 145,980   $ 3,152,658   $ 247,829 (1) Other International primarily consists of EOG's United Kingdom, China and Canada operations.
Assets by Reportable Segment	Total assets by reportable segment are presented below at September 30, 2018 and December 31, 2017 (in thousands):   At September 30, 2018   At December 31, 2017 Total Assets       United States $ 32,656,676   $ 28,312,599 Trinidad 619,127   974,477 Other International (1) 361,933   546,002 Total $ 33,637,736   $ 29,833,078 (1) Other International primarily consists of EOG's United Kingdom, China and Canada operations.

v3.10.0.1

Asset Retirement Obligations (Tables)	9 Months Ended
	Sep. 30, 2018
Asset Retirement Obligation [Abstract]
Asset Retirement Obligation Rollforward Analysis	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 periods ended September 30, 2018 and 2017 (in thousands):   Nine Months Ended   September 30,   2018   2017 Carrying Amount at January 1 $ 946,848   $ 912,926 Liabilities Incurred 63,443   30,114 Liabilities Settled (1) (15,319 )   (53,638 ) Accretion 27,306   25,963 Revisions (39,137 )   (1,791 ) Foreign Currency Translations (2,197 )   16,902 Carrying Amount at September 30 $ 980,944   $ 930,476         Current Portion $ 18,209   $ 23,606 Noncurrent Portion $ 962,735   $ 906,870 (1) Includes settlements related to asset sales.

v3.10.0.1

Exploratory Well Costs (Tables)	9 Months Ended
	Sep. 30, 2018
Capitalized Exploratory Well Costs [Abstract]
Net Changes In Capitalized Exploratory Well Costs	EOG's net changes in capitalized exploratory well costs for the nine-month period ended September 30, 2018, are presented below (in thousands):   Nine Months Ended   September 30, 2018 Balance at January 1 $ 2,167 Additions Pending the Determination of Proved Reserves 6,497 Reclassifications to Proved Properties (5,346 ) Costs Charged to Expense (433 ) Balance at September 30 $ 2,885

v3.10.0.1

Fair Value Measurements (Tables)	9 Months Ended
	Sep. 30, 2018
Fair Value Disclosures [Abstract]
Fair Value Assets and Liabilities Measured On Recurring Basis	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, 2018 and December 31, 2017 (in millions):   Fair Value Measurements Using:   Quoted Prices in Active Markets (Level 1)   Significant Other Observable Inputs (Level 2)   Significant Unobservable Inputs (Level 3)   Total At September 30, 2018               Financial Assets:               Crude Oil Basis Swaps $ —   $ 35   $ —   $ 35 Financial Liabilities:               Crude Oil Swaps $ —   $ 159   $ —   $ 159 Crude Oil Basis Swaps —   2   —   2                 At December 31, 2017               Financial Assets:               Natural Gas Swaps $ —   $ 2   $ —   $ 2 Natural Gas Options/Collars —   6   —   6 Financial Liabilities:               Crude Oil Swaps $ —   $ 38   $ —   $ 38 Crude Oil Basis Swaps —   19   —   19

v3.10.0.1

Risk Management Activities (Tables)	9 Months Ended
	Sep. 30, 2018
Derivatives, Fair Value [Line Items]
Schedule of Derivative Instruments in Statement of Financial Position, Fair Value [Table Text Block]	The following table sets forth the amounts and classification of EOG's outstanding financial derivative instruments at September 30, 2018 and December 31, 2017.  Certain amounts may be presented on a net basis on the Condensed Consolidated Financial Statements when such amounts are with the same counterparty and subject to a master netting arrangement (in millions):          Fair Value at Description   Location on Balance Sheet   September 30, 2018   December 31, 2017 Asset Derivatives             Crude oil and natural gas derivative contracts -             Current portion   Assets from Price Risk Management Activities   $ 2   $ 8 Noncurrent portion   Other Assets   5   — Liability Derivatives             Crude oil and natural gas derivative contracts -             Current portion   Liabilities from Price Risk Management Activities (1)   $ 133   $ 50 Noncurrent portion   Other Liabilities   —   7 (1) The current portion of Liabilities from Price Risk Management Activities consists of gross liabilities of $161 million, partially offset by gross assets of $28 million at September 30, 2018, and gross liabilities of $55 million, partially offset by gross assets of $5 million at December 31, 2017.
Crude Oil [Member] | Midland Differential Basis Swaps [Member]
Derivatives, Fair Value [Line Items]
Schedule of Derivative Instruments	Presented below is a comprehensive summary of EOG's Midland Differential basis swap contracts for the nine months ended September 30, 2018. The weighted average price differential expressed in dollars per barrel ($/Bbl) represents the amount of reduction 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)       2018           January 1, 2018 through October 31, 2018 (closed)   15,000   $ 1.063   November 1, 2018 through December 31, 2018   15,000   1.063               2019           January 1, 2019 through December 31, 2019   20,000   $ 1.075
Crude Oil [Member] | Gulf Coast Differential Basis Swap [Member]
Derivatives, Fair Value [Line Items]
Schedule of Derivative Instruments	Presented below is a comprehensive summary of EOG's Gulf Coast Differential basis swap contracts for the nine months ended September 30, 2018. 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)       2018           January 1, 2018 through September 30, 2018 (closed)   37,000   $ 3.818   October 2018 (closed)   52,000   3.911   November 1, 2018 through December 31, 2018   52,000   3.911               2019           January 1, 2019 through December 31, 2019   10,000   $ 5.558
Crude Oil [Member] | Price Swaps [Member]
Derivatives, Fair Value [Line Items]
Schedule of Derivative Instruments	Presented below is a comprehensive summary of EOG's crude oil price swap contracts for the nine months ended September 30, 2018, with notional volumes expressed in Bbld and prices expressed in $/Bbl. Crude Oil Price Swap Contracts     Volume (Bbld)   Weighted Average Price ($/Bbl) 2018         January 1, 2018 through September 30, 2018 (closed)   134,000   $ 60.04 October 1, 2018 through December 31, 2018   134,000   60.04
Natural Gas [Member] | Price Swaps [Member]
Derivatives, Fair Value [Line Items]
Schedule of Derivative Instruments	Presented below is a comprehensive summary of EOG's natural gas price swap contracts for the nine months ended September 30, 2018, 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) 2018         March 1, 2018 through October 31, 2018 (closed)   35,000   $ 3.00 November 2018   35,000   3.00
Natural Gas [Member] | Options [Member]
Derivatives, Fair Value [Line Items]
Schedule of Derivative Instruments	Presented below is a comprehensive summary of EOG's natural gas call and put option contracts for the nine months ended September 30, 2018, with notional volumes expressed in MMBtud and prices expressed in $/MMBtu. Natural Gas Option Contracts   Call Options Sold   Put Options Purchased   Volume (MMBtud)   Weighted Average Price ($/MMBtu)   Volume (MMBtud)   Weighted Average Price ($/MMBtu) 2018               March 1, 2018 through October 31, 2018 (closed) 120,000   $ 3.38   96,000   $ 2.94 November 2018 120,000   3.38   96,000   2.94

v3.10.0.1

Summary of Significant Accounting Policies (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended		12 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017	Dec. 31, 2017	Jan. 01, 2018
Total Operating Revenues and Other	$ 4,781,624	$ 2,644,844	$ 12,700,863	$ 7,867,881
Gathering and Processing Costs	114,063	32,590	324,577	105,480
Marketing Costs	1,326,974	793,536	3,853,827	2,320,671
Total Operating Expenses	3,274,937	2,430,008	9,354,657	7,417,391
Operating Income (Loss)	1,506,687	214,836	3,346,206	450,490
Accounts Receivable From Contracts With Customers	1,812,000		1,812,000			$ 1,343,000
Provisional Reduction in the Income Tax Provision			$ 52,000		$ 2,200,000
Statutory Federal Income Tax Rate (in hundredths)			21.00%		35.00%
Repatriation Tax of Foreign Earnings			$ 40,000		$ 179,000
Crude Oil and Condensate
Revenues	2,655,278	1,451,410	7,134,114	4,326,925
Natural Gas Liquids
Revenues	353,704	180,038	861,473	480,389
Natural Gas
Revenues	311,713	220,402	912,324	675,012
Gathering, Processing and Marketing
Revenues	1,360,992	$ 784,368	3,899,250	$ 2,289,702
Amounts Without Adoption of ASU 2014-09
Total Operating Revenues and Other	4,719,377		12,538,107
Gathering and Processing Costs	56,899		177,849
Marketing Costs	1,321,891		3,837,799
Total Operating Expenses	3,212,690		9,191,901
Operating Income (Loss)	1,506,687		3,346,206
Amounts Without Adoption of ASU 2014-09 | Crude Oil and Condensate
Revenues	2,655,278		7,134,114
Amounts Without Adoption of ASU 2014-09 | Natural Gas Liquids
Revenues	352,084		856,628
Amounts Without Adoption of ASU 2014-09 | Natural Gas
Revenues	256,169		770,441
Amounts Without Adoption of ASU 2014-09 | Gathering, Processing and Marketing
Revenues	1,355,909		3,883,222
Effect of Change
Total Operating Revenues and Other	62,247		162,756
Gathering and Processing Costs	57,164		146,728
Marketing Costs	5,083		16,028
Total Operating Expenses	62,247		162,756
Operating Income (Loss)	0		0
Effect of Change | Crude Oil and Condensate
Revenues	0		0
Effect of Change | Natural Gas Liquids
Revenues	1,620		4,845
Effect of Change | Natural Gas
Revenues	55,544		141,883
Effect of Change | Gathering, Processing and Marketing
Revenues	$ 5,083		$ 16,028

v3.10.0.1

Stock-Based Compensation (Details) - USD ($) $ / shares in Units, $ in Thousands		3 Months Ended		9 Months Ended
		Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018		Sep. 30, 2017
Stock Options/SARs and Employee Stock Purchase Plan (ESPP) Disclosures [Line Items]
Total Operating Expenses		$ 3,274,937	$ 2,430,008	$ 9,354,657		$ 7,417,391
Compensation expense related to the company's stock-based compensation plans		$ 49,000	43,500	$ 116,300		101,500
Common Shares Available for Grant		13,700,000		13,700,000
Stock Options and SARs [Member]
Stock Options/SARs and Employee Stock Purchase Plan (ESPP) Disclosures [Line Items]
Stock-based compensation expense related to stock options, SAR and ESPP grants		$ 21,700	$ 20,900	$ 45,400		$ 42,900
Unrecognized compensation expense	[1]	$ 119,700		$ 119,700
Weighted average period over which unrecognized compensation expense will be recognized (in years)				2 years 3 months 18 days
Weighted Average Fair Values And Valuation Assumptions Used To Value Stock Option/SARs, ESPP, and Performance Units/Stock Stock-Based Compensation [Abstract]
Weighted Average Fair Value of Grants (price per share)				$ 33.49		$ 23.94
Expected Volatility (in hundredths)				28.22%		28.28%
Risk-Free Interest Rate (in hundredths)				2.68%		1.52%
Dividend Yield (in hundredths)				0.72%		0.75%
Expected Life (in years)				5 years		5 years 1 month 6 days
Stock Options and SARs Rollforward [Abstract]
Outstanding at January 1 (in shares)				9,103,000		9,850,000
Granted (in shares)				1,884,000		2,260,000
Exercised (1) (in shares)	[1]			(2,144,000)		(1,674,000)
Forfeited (in shares)				(167,000)		(269,000)
Outstanding at September 30 (2) (in shares)	[2]	8,676,000	10,167,000	8,676,000		10,167,000
Stock Options and SARs Vested or Expected to Vest (in shares)	[3]	8,316,000	9,799,000	8,316,000		9,799,000
Stock Options and SARs Exercisable at September 30 (in shares)	[4]	4,202,000	5,517,000	4,202,000		5,517,000
Intrinsic Value of Stock Options/SARs Exercised	[1]			$ 103,700		$ 66,600
Weighted Average Remaining Contractual Life for Stock Options/SARs Outstanding (in years)				4 years 9 months 18 days		4 years 3 months 18 days
Intrinsic Value of Stock Options/SARs Vested or Expected to Vest	[1]	$ 261,900	$ 145,900	$ 261,900		$ 145,900
Weighted average remaining contractual life for stock options/SARs vested or expected to vest (in years)				4 years 8 months 12 days		4 years 3 months 18 days
Aggregate Intrinsic Value for Exercisable Units	[1]	175,500	123,200	$ 175,500		$ 123,200
Weighted average remaining contractual life for exercisable options/SARs (in years)				3 years 4 months 24 days	[1]	2 years 9 months 18 days
Weighted Average Grant Price Stock Option and SARs [Rollforward]
Intrinsic Value of Stock Options/SARs Outstanding	[1]	$ 269,100	$ 147,800	$ 269,100		$ 147,800
Outstanding at January 1 (price per share)				$ 83.89		$ 75.53
Granted (price per share)				126.65		96.24
Exercised (1) (price per share)	[1]			69.62		55.63
Forfeited (price per share)				91.89		90.22
Outstanding at September 30 (2) (price per share)	[2]	$ 96.55	$ 83.02	96.55		83.02
Vested or Expected to Vest (3) (price per share)	[3]	96.08	82.69	96.08		82.69
Exercisable at September 30 (4) (price per share)	[4]	$ 85.80	$ 75.59	85.80		75.59
ESPP [Member]
Weighted Average Fair Values And Valuation Assumptions Used To Value Stock Option/SARs, ESPP, and Performance Units/Stock Stock-Based Compensation [Abstract]
Weighted Average Fair Value of Grants (price per share)				$ 25.52		$ 22.10
Expected Volatility (in hundredths)				24.36%		26.96%
Risk-Free Interest Rate (in hundredths)				1.86%		0.89%
Dividend Yield (in hundredths)				0.64%		0.71%
Expected Life (in years)				6 months		6 months
Restricted Stock And Restricted Stock Units [Member]
Stock Options/SARs and Employee Stock Purchase Plan (ESPP) Disclosures [Line Items]
Unrecognized compensation expense	[1]	$ 194,500		$ 194,500
Weighted average period over which unrecognized compensation expense will be recognized (in years)				2 years 2 months 12 days
Intrinsic value released during the year	[1]			$ 80,200		$ 81,600
Aggregate intrinsic value of stock and units outstanding	[1]	489,700	$ 386,600	489,700		386,600
Restricted Stock/Restricted Stock Units [Roll Forward]
Share-Based Compensation Arrangement By Restricted Stock And Restricted Stock Units Compensation Cost	[1]	$ 17,500	$ 15,800	$ 58,800		$ 50,000
Outstanding at January 1 (in shares)				3,905,000		3,962,000
Granted (in shares)				792,000		1,061,000
Released (1) (in shares)	[5]			(708,000)		(837,000)
Forfeited (in shares)				(150,000)		(190,000)
Outstanding at September 30 (2) (in shares)	[6]	3,839,000	3,996,000	3,839,000		3,996,000
Weighted Average Grant Price Restricted Stock and Restricted Stock Units [Roll Forward]
Outstanding at January 1 (price per share)				$ 88.57		$ 79.63
Granted (price per share)				117.67		97.26
Released (1) (price per share)	[5]			77.46		59.67
Forfeited (price per share)				91.36		84.66
Outstanding at September 30 (2) (price per share)	[6]	$ 96.52	$ 88.25	$ 96.52		$ 88.25
Performance Units and Performance Stock [Member]
Stock Options/SARs and Employee Stock Purchase Plan (ESPP) Disclosures [Line Items]
Compensation expense related to the company's stock-based compensation plans	[1]	$ 9,800	$ 6,800	$ 12,100		$ 8,600
Unrecognized compensation expense		11,000		$ 11,000
Weighted average period over which unrecognized compensation expense will be recognized (in years)				1 year 8 months 12 days
Intrinsic value released during the year				$ 17,700		23,600
Aggregate intrinsic value of stock and units outstanding		$ 68,000	$ 48,600	$ 68,000		$ 48,600
Minimum Performance Units and Stock Allowed to be Outstanding						143,610
Maximum Performance Units and Stock Allowed to be Outstanding						921,940
Restricted Stock/Restricted Stock Units [Roll Forward]
Outstanding at January 1 (in shares)				502		545
Granted (in shares)				107		78
Granted for Performance Multiple (1)				72		119
Released (1) (in shares)				148		240
Forfeited (in shares)				0		0
Outstanding at September 30 (2) (in shares)		533	502	533		502
Weighted Average Grant Price Restricted Stock and Restricted Stock Units [Roll Forward]
Outstanding at January 1 (price per share)				$ 90.96		$ 80.92
Granted (price per share)				127.00		96.29
Granted for Performance Multiple (1) (in dollars per share)				101.87		84.43
Released (1) (price per share)				84.43		66.69
Forfeited (price per share)				0.00		0.00
Outstanding at September 30 (2) (price per share)		$ 101.50	$ 90.96	$ 101.50		$ 90.96
Performance Units and Performance Stock Disclosures [Abstract]
Performance Period for Performance Units and Shares				3 years
Minimum Performance Multiple at the Completion of the Performance Period				0.00%
Maximum Performance Multiple at the Completion of the Performance Period				200.00%
Lease and Well
Stock Options/SARs and Employee Stock Purchase Plan (ESPP) Disclosures [Line Items]
Compensation expense related to the company's stock-based compensation plans		$ 12,900	$ 9,500	$ 37,100		$ 30,000
Gathering and Processing Costs
Stock Options/SARs and Employee Stock Purchase Plan (ESPP) Disclosures [Line Items]
Compensation expense related to the company's stock-based compensation plans		100	100	300		500
Exploration Costs
Stock Options/SARs and Employee Stock Purchase Plan (ESPP) Disclosures [Line Items]
Compensation expense related to the company's stock-based compensation plans		5,800	4,700	18,400		16,100
General and Administrative
Stock Options/SARs and Employee Stock Purchase Plan (ESPP) Disclosures [Line Items]
Compensation expense related to the company's stock-based compensation plans		$ 30,200	$ 29,200	$ 60,500		$ 54,900
[1] The total intrinsic value of stock options/SARs exercised for the nine months ended September 30, 2018 and 2017 was $103.7 million and $66.6 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, 2018 and 2017 was $269.1 million and $147.8 million, respectively. At September 30, 2018 and 2017, the weighted average remaining contractual life was 4.8 years and 4.3 years, respectively. [3] The total intrinsic value of stock options/SARs vested or expected to vest at September 30, 2018 and 2017 was $261.9 million and $145.9 million, respectively. At September 30, 2018 and 2017, the weighted average remaining contractual life was 4.7 years and 4.3 years, respectively. [4] The total intrinsic value of stock options/SARs exercisable at September 30, 2018 and 2017 was $175.5 million and $123.2 million, respectively. At September 30, 2018 and 2017, the weighted average remaining contractual life was 3.4 years and 2.8 years, respectively. [5] The total intrinsic value of restricted stock and restricted stock units released for the nine months ended September 30, 2018 and 2017 was $80.2 million and $81.6 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. [6] The total intrinsic value of restricted stock and restricted stock units outstanding at September 30, 2018 and 2017 was $489.7 million and $386.6 million, respectively.

v3.10.0.1

Net Income Per Share (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Numerator for Basic and Diluted Earnings Per Share - [Abstract]
Net Income	$ 1,190,952	$ 100,541	$ 2,526,272	$ 152,111
Denominator for Basic Earnings Per Share - [Abstract]
Weighted Average Shares	577,254	574,783	576,431	574,370
Denominator for Diluted Earnings Per Share - [Abstract]
Adjusted Diluted Weighted Average Shares	581,559	578,736	580,442	578,453
Antidilutive Securities Excluded from Computation of Earnings Per Share [Abstract]
Anti-dilutive Securities excluded from Diluted Earnings Per Share Calculation	500	4,200	200	3,600
Net Income Per Share
Basic	$ 2.06	$ 0.17	$ 4.38	$ 0.26
Diluted	$ 2.05	$ 0.17	$ 4.35	$ 0.26
Stock Options And SARs [Member]
Potential Dilutive Common Shares - [Abstract]
Common Shares Attributable to Dilutive Effect of Share-Based Payment Arrangments	1,432	1,451	1,317	1,518
Restricted Stock/Units and Performance Units/Stock [Member]
Potential Dilutive Common Shares - [Abstract]
Common Shares Attributable to Dilutive Effect of Share-Based Payment Arrangments	2,873	2,502	2,694	2,565

v3.10.0.1

Supplemental Cash Flow Information (Details) - USD ($) $ in Thousands		9 Months Ended
		Sep. 30, 2018	Sep. 30, 2017
Supplemental Cash Flow Information [Abstract]
Interest (1)	[1]	$ 172,076	$ 202,320
Income Taxes, Net of Refunds Received		81,059	92,391
Interest Costs Capitalized		18,000	21,000
Accrued Capital Expenditures		702,000	545,000
Non-Cash Property Exchanges		222,000	$ 214,000
Non-Cash Other Property, Plant and Equipment		$ 49,000
[1] Net of capitalized interest of $18 million and $21 million for the nine months ended September 30, 2018 and 2017, respectively.

v3.10.0.1

Segment Information (Details) - USD ($) $ in Thousands		3 Months Ended		9 Months Ended
		Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017	Dec. 31, 2017
Schedule of Segment Reporting Information By Segment [Abstract]
Operating Revenues and Other		$ 4,781,624	$ 2,644,844	$ 12,700,863	$ 7,867,881
Operating Income (Loss)		1,506,687	214,836	3,346,206	450,490
Other Income (Expense), Net		3,308	226	(4,516)	8,349
Interest Expense, Net		(63,632)	(69,082)	(189,032)	(211,010)
Income Before Income Taxes		1,446,363	145,980	3,152,658	247,829
Total Assets		33,637,736		33,637,736		$ 29,833,078
United States [Member]
Schedule of Segment Reporting Information By Segment [Abstract]
Operating Revenues and Other		4,653,342	2,569,867	12,339,086	7,620,601
Operating Income (Loss)		1,458,641	207,173	3,251,377	457,018
Total Assets		32,656,676		32,656,676		28,312,599
Trinidad [Member]
Schedule of Segment Reporting Information By Segment [Abstract]
Operating Revenues and Other		84,648	63,800	247,272	210,022
Operating Income (Loss)		48,988	21,739	117,106	70,512
Total Assets		619,127		619,127		974,477
Other International [Member]
Schedule of Segment Reporting Information By Segment [Abstract]
Operating Revenues and Other	[1]	43,634	11,177	114,505	37,258
Operating Income (Loss)	[1]	(942)	$ (14,076)	(22,277)	$ (77,040)
Total Assets	[1]	$ 361,933		$ 361,933		$ 546,002
[1] Other International primarily consists of EOG's United Kingdom, China and Canada operations.

v3.10.0.1

Asset Retirement Obligations (Details) - USD ($) $ in Thousands		9 Months Ended
		Sep. 30, 2018	Sep. 30, 2017
Asset Retirement Obligation [Abstract]
Carrying Amount at January 1		$ 946,848	$ 912,926
Liabilities Incurred		63,443	30,114
Liabilities Settled (1)	[1]	(15,319)	(53,638)
Accretion		27,306	25,963
Revisions		(39,137)	(1,791)
Foreign Currency Translations		(2,197)	16,902
Carrying Amount at September 30		980,944	930,476
Current Portion		18,209	23,606
Noncurrent Portion		$ 962,735	$ 906,870
[1] Includes settlements related to asset sales.

v3.10.0.1

Exploratory Well Costs (Details) $ in Thousands	9 Months Ended
	Sep. 30, 2018 USD ($)
Capitalized Exploratory Well Costs that are Pending Determination of Proved Reserves [Roll Forward]
Balance at January 1	$ 2,167
Additions Pending the Determination of Proved Reserves	6,497
Reclassifications to Proved Properties	(5,346)
Costs Charged to Expense	(433)
Balance at September 30	$ 2,885

v3.10.0.1

Pension and Postretirement Benefits (Details) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017
Defined Benefit and Defined Contribution Plan Disclosure [Line Items]
Total Pension Plans Costs	$ 30	$ 27

v3.10.0.1

Long-Term Debt and Common Stock (Details) - USD ($)	9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Dec. 31, 2017
Debt Instrument [Abstract]
Dividends Payable, Amount Per Share Before Increase	$ 0.1850
Dividends Payable, Amount Per Share After Increase	$ 0.22
Commercial Paper [Member]
Line of Credit Facility [Line Items]
Borrowings Outstanding	$ 0		$ 0
Average Outstanding Amount	$ 11,000,000	$ 9,000,000
Weighted average interest rate (in hundredths)	1.97%	1.39%
Senior Notes [Member]
Line of Credit Facility [Line Items]
Maturities of Senior Debt	$ 350,000,000
Debt Instrument, Interest Rate, Effective Percentage	6.875%
Uncommitted Credit Facility [Member]
Line of Credit Facility [Line Items]
Borrowings Outstanding	$ 0		0
Revolving Credit Agreement 2020 [Member]
Line of Credit Facility [Line Items]
Borrowings Outstanding	0		$ 0
Line of Credit Facility, Maximum Borrowing Capacity	$ 2,000,000,000
Line of Credit Facility, Expiration Date	Jul. 21, 2020
Eurodollar [Member] | Revolving Credit Agreement 2020 [Member]
Line of Credit Facility [Line Items]
Weighted average interest rate (in hundredths)	3.16%
Base Rate [Member] | Revolving Credit Agreement 2020 [Member]
Line of Credit Facility [Line Items]
Weighted average interest rate (in hundredths)	5.25%

v3.10.0.1

Fair Value Measurements (Details) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2018	Dec. 31, 2017
Proved Oil and Gas Properties, Other Property, Plant and Equipment and Other Assets [Abstract]
Proved Oil and Gas Properties and Other Assets Carrying Amount	$ 165
Proved Oil and Gas Properties and Other Assets Written Down During the Period - Fair value at End of Period	131
Pretax Impairment Charges for Proved Oil and Gas Properties and Other Assets	34
Pretax Impairment Charge for a Commodity Price-Related Write-Down of Other Assets	21
Debt Disclosure [Abstract]
Aggregate Principal Amount of Current and Long-Term Debt	6,390	$ 6,390
Estimated Fair Value of Debt	6,400	6,602
Commodity Contract [Member] | Crude Oil [Member] | Price Swaps [Member]
Financial Liabilities:
Financial and Nonfinancial Liabilities, Fair Value Disclosure	159	38
Commodity Contract [Member] | Crude Oil [Member] | Price Swaps [Member] | Fair Value, Inputs, Level 1 [Member]
Financial Liabilities:
Financial and Nonfinancial Liabilities, Fair Value Disclosure	0	0
Commodity Contract [Member] | Crude Oil [Member] | Price Swaps [Member] | Fair Value, Inputs, Level 2 [Member]
Financial Liabilities:
Financial and Nonfinancial Liabilities, Fair Value Disclosure	159	38
Commodity Contract [Member] | Crude Oil [Member] | Price Swaps [Member] | Fair Value, Inputs, Level 3 [Member]
Financial Liabilities:
Financial and Nonfinancial Liabilities, Fair Value Disclosure	0	0
Commodity Contract [Member] | Crude Oil [Member] | Basis Swaps [Member]
Financial Assets: [Abstract]
Assets, Fair Value Disclosure	35
Financial Liabilities:
Financial and Nonfinancial Liabilities, Fair Value Disclosure	2	19
Commodity Contract [Member] | Crude Oil [Member] | Basis Swaps [Member] | Fair Value, Inputs, Level 1 [Member]
Financial Assets: [Abstract]
Assets, Fair Value Disclosure	0
Financial Liabilities:
Financial and Nonfinancial Liabilities, Fair Value Disclosure		0
Commodity Contract [Member] | Crude Oil [Member] | Basis Swaps [Member] | Fair Value, Inputs, Level 2 [Member]
Financial Assets: [Abstract]
Assets, Fair Value Disclosure	35
Financial Liabilities:
Financial and Nonfinancial Liabilities, Fair Value Disclosure	2	19
Commodity Contract [Member] | Crude Oil [Member] | Basis Swaps [Member] | Fair Value, Inputs, Level 3 [Member]
Financial Assets: [Abstract]
Assets, Fair Value Disclosure	0
Financial Liabilities:
Financial and Nonfinancial Liabilities, Fair Value Disclosure	$ 0	0
Commodity Contract [Member] | Natural Gas [Member] | Price Swaps [Member]
Financial Assets: [Abstract]
Assets, Fair Value Disclosure		2
Commodity Contract [Member] | Natural Gas [Member] | Price Swaps [Member] | Fair Value, Inputs, Level 1 [Member]
Financial Assets: [Abstract]
Assets, Fair Value Disclosure		0
Commodity Contract [Member] | Natural Gas [Member] | Price Swaps [Member] | Fair Value, Inputs, Level 2 [Member]
Financial Assets: [Abstract]
Assets, Fair Value Disclosure		2
Commodity Contract [Member] | Natural Gas [Member] | Price Swaps [Member] | Fair Value, Inputs, Level 3 [Member]
Financial Assets: [Abstract]
Assets, Fair Value Disclosure		0
Commodity Contract [Member] | Natural Gas [Member] | Options/Collars [Member]
Financial Assets: [Abstract]
Assets, Fair Value Disclosure		6
Commodity Contract [Member] | Natural Gas [Member] | Options/Collars [Member] | Fair Value, Inputs, Level 1 [Member]
Financial Assets: [Abstract]
Assets, Fair Value Disclosure		0
Commodity Contract [Member] | Natural Gas [Member] | Options/Collars [Member] | Fair Value, Inputs, Level 2 [Member]
Financial Assets: [Abstract]
Assets, Fair Value Disclosure		6
Commodity Contract [Member] | Natural Gas [Member] | Options/Collars [Member] | Fair Value, Inputs, Level 3 [Member]
Financial Assets: [Abstract]
Assets, Fair Value Disclosure		$ 0

v3.10.0.1

Risk Management Activities (Details)		9 Months Ended
		Sep. 30, 2018 USD ($) MMBTU $ / bbl $ / MMBTU bbl	Dec. 31, 2017 USD ($)
Derivatives, Fair Value [Line Items]
Assets from Price Risk Management Activities		$ 1,569,000	$ 7,699,000
Liabilities from Price Risk Management Activities		132,618,000	50,429,000
Derivative Collateral [Abstract]
Collateral Had on Derivative		0	0
Collateral Held on Derivative		0	0
Other Assets [Member] | Price Risk Derivative [Member]
Derivatives, Fair Value [Line Items]
Other Assets		5,000,000	0
Liabilities From Price Risk Management Activities [Member]
Derivatives, Fair Value [Line Items]
Assets from Price Risk Management Activities		28,000,000	5,000,000
Liabilities from Price Risk Management Activities		161,000,000	55,000,000
Liabilities From Price Risk Management Activities [Member] | Price Risk Derivative [Member]
Derivatives, Fair Value [Line Items]
Liabilities from Price Risk Management Activities	[1]	133,000,000	50,000,000
Other Liabilities [Member] | Price Risk Derivative [Member]
Derivatives, Fair Value [Line Items]
Other Liabilities		0	7,000,000
Assets From Price Risk Management Activities [Member] | Price Risk Derivative [Member]
Derivatives, Fair Value [Line Items]
Assets from Price Risk Management Activities		$ 2,000,000	$ 8,000,000
Crude Oil [Member] | Midland Differential Basis Swaps [Member] | Derivative Contracts - January through October (closed) [Member]
Derivatives, Fair Value [Line Items]
Volume (Bbld) | bbl		15,000
Derivative, Swap Type, Average Fixed Price | $ / bbl		1.063
Crude Oil [Member] | Midland Differential Basis Swaps [Member] | Derivative Contracts - November through December [Member]
Derivatives, Fair Value [Line Items]
Volume (Bbld) | bbl		15,000
Derivative, Swap Type, Average Fixed Price | $ / bbl		1.063
Crude Oil [Member] | Midland Differential Basis Swaps [Member] | Derivative Contracts Year Two - January through December [Member]
Derivatives, Fair Value [Line Items]
Volume (Bbld) | bbl		20,000
Derivative, Swap Type, Average Fixed Price | $ / bbl		1.075
Crude Oil [Member] | Gulf Coast Differential Basis Swap [Member] | Derivative Contracts - November through December [Member]
Derivatives, Fair Value [Line Items]
Volume (Bbld) | bbl		52,000
Derivative, Swap Type, Average Fixed Price | $ / bbl		3.911
Crude Oil [Member] | Gulf Coast Differential Basis Swap [Member] | Derivative Contracts Year Two - January through December [Member]
Derivatives, Fair Value [Line Items]
Volume (Bbld) | bbl		10,000
Derivative, Swap Type, Average Fixed Price | $ / bbl		5.558
Crude Oil [Member] | Gulf Coast Differential Basis Swap [Member] | Derivative Contracts - January through September (closed) [Member]
Derivatives, Fair Value [Line Items]
Volume (Bbld) | bbl		37,000
Derivative, Swap Type, Average Fixed Price | $ / bbl		3.818
Crude Oil [Member] | Gulf Coast Differential Basis Swap [Member] | Derivative Contracts - October 2018 (closed) [Member]
Derivatives, Fair Value [Line Items]
Volume (Bbld) | bbl		52,000
Derivative, Swap Type, Average Fixed Price | $ / bbl		3.911
Crude Oil [Member] | Price Swaps [Member] | Derivative Contracts - January through September (closed) [Member]
Derivatives, Fair Value [Line Items]
Volume (Bbld) | bbl		134,000
Derivative, Swap Type, Average Fixed Price | $ / bbl		60.04
Crude Oil [Member] | Price Swaps [Member] | Derivative Contracts - October through December [Member]
Derivatives, Fair Value [Line Items]
Volume (Bbld) | bbl		134,000
Derivative, Swap Type, Average Fixed Price | $ / bbl		60.04
Natural Gas [Member] | Price Swaps [Member] | Derivative Contracts - March through October (closed) [Member]
Derivatives, Fair Value [Line Items]
Derivative, Swap Type, Average Fixed Price | $ / MMBTU		3.00
Volume (MMBtud) | MMBTU		35,000
Natural Gas [Member] | Price Swaps [Member] | Derivative Contracts - November [Member]
Derivatives, Fair Value [Line Items]
Derivative, Swap Type, Average Fixed Price | $ / MMBTU		3.00
Volume (MMBtud) | MMBTU		35,000
Natural Gas [Member] | Call Option [Member] | Derivative Contracts - March through October (closed) [Member]
Derivatives, Fair Value [Line Items]
Volume (MMBtud) | MMBTU		120,000
Derivative, Average Price Risk Option Strike Price | $ / MMBTU		3.38
Natural Gas [Member] | Call Option [Member] | Derivative Contracts - November [Member]
Derivatives, Fair Value [Line Items]
Volume (MMBtud) | MMBTU		120,000
Derivative, Average Price Risk Option Strike Price | $ / MMBTU		3.38
Natural Gas [Member] | Put Option [Member] | Derivative Contracts - March through October (closed) [Member]
Derivatives, Fair Value [Line Items]
Volume (MMBtud) | MMBTU		96,000
Derivative, Average Price Risk Option Strike Price | $ / MMBTU		2.94
Natural Gas [Member] | Put Option [Member] | Derivative Contracts - November [Member]
Derivatives, Fair Value [Line Items]
Volume (MMBtud) | MMBTU		96,000
Derivative, Average Price Risk Option Strike Price | $ / MMBTU		2.94
[1] The current portion of Liabilities from Price Risk Management Activities consists of gross liabilities of $161 million, partially offset by gross assets of $28 million at September 30, 2018, and gross liabilities of $55 million, partially offset by gross assets of $5 million at December 31, 2017.

v3.10.0.1

Acquisitions and Divestitures (Details) - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017
Discontinued Operations and Disposal Groups [Abstract]
Gains (Losses) on Asset Dispositions, Net	$ 94,658	$ (33,876)
Proceeds on Asset Dispositions	11,582	$ 191,593
Book Value of Assets Held-For-Sale	235,000
Asset Held-For-Sale Liabilities	$ 65,000

This regulatory filing also includes additional resources:
eog2018093010q.pdf