EOG EOG Resources Inc

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(1)	The total intrinsic value of stock options/SARs exercised for the six months ended June 30, 2018 and 2017 was $74.5 million and $33.5 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 June 30, 2018 and 2017 was $277.2 million and $147.8 million, respectively. At June 30, 2018 and 2017, the weighted average remaining contractual life was 4.3 years and 3.6 years, respectively.

(3)	The total intrinsic value of stock options/SARs vested or expected to vest at June 30, 2018 and 2017 was $266.2 million and $145.7 million, respectively. At June 30, 2018 and 2017, the weighted average remaining contractual life was 4.3 years and 3.5 years, respectively.

(4)	The total intrinsic value of stock options/SARs exercisable at June 30, 2018 and 2017 was $134.2 million and $120.9 million, respectively. At June 30, 2018 and 2017, the weighted average remaining contractual life was 2.7 years and 2.2 years, respectively.

(1)	The total intrinsic value of restricted stock and restricted stock units released for the six months ended June 30, 2018 and 2017 was $34.9 million and $40.4 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 June 30, 2018 and 2017 was $468.2 million and $348.4 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 six months ended June 30, 2017 was approximately $9.0 million. 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 June 30, 2018 and 2017 was approximately $71.4 million and $52.0 million, respectively.

(4)	Upon the application of the relevant performance multiple at the completion of each of the remaining Performance Periods, a minimum of 292,054 and a maximum of 856,218 Performance Awards could be outstanding.

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(1)	Net of capitalized interest of $11 million and $14 million for the six months ended June 30, 2018 and 2017, respectively.

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

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

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(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 $261 million, partially offset by gross assets of $66 million at June 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 $0.39 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 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 $0.40 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 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 $60 million and $154 million for the six-month periods ended June 30, 2018 and 2017, respectively, related to non-cash property exchanges.

(2)	Property acquisitions included $23 million for the six-month period ended June 30, 2018 related to non-cash property exchanges.

(3)	Other property, plant and equipment included $48 million of non-cash additions for the six-month period ended June 30, 2018 in connection with 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 126,925 total shares for the quarter ended June 30, 2018, and the 281,481 total shares for the six months ended June 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 second quarter of 2018, EOG did not repurchase any shares under the Board-authorized repurchase program.

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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 June 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 June 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	6 Months Ended
	Jun. 30, 2018	Jul. 25, 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
Entity Common Stock, Shares Outstanding		579,200,784
Document Fiscal Year Focus	2018
Document Fiscal Period Focus	Q2
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Jun. 30, 2018

v3.10.0.1

Consolidated Statements of Income and Comprehensive Income - USD ($) shares in Thousands, $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Operating Revenues and Other
Crude Oil and Condensate	$ 2,377,528	$ 1,445,454	$ 4,478,836	$ 2,875,515
Natural Gas Liquids	286,354	146,907	507,769	300,351
Natural Gas	300,845	224,008	600,611	454,610
Gains (Losses) on Mark-to-Market Commodity Derivative Contracts	(185,883)	9,446	(245,654)	71,466
Gathering, Processing and Marketing	1,436,436	778,797	2,538,258	1,505,334
Losses on Asset Dispositions, Net	(6,317)	(8,916)	(21,286)	(25,674)
Other, Net	29,114	16,776	60,705	41,435
Total	4,238,077	2,612,472	7,919,239	5,223,037
Operating Expenses
Lease and Well	314,604	255,186	614,668	510,963
Transportation Costs	177,797	186,356	354,754	365,070
Gathering and Processing Costs	109,169	34,746	210,514	72,890
Exploration Costs	47,478	34,711	82,314	91,605
Dry Hole Costs	4,902	27	4,902	27
Impairments	51,708	78,934	116,317	272,121
Marketing Costs	1,420,463	790,599	2,526,853	1,527,135
Depreciation, Depletion and Amortization	848,674	865,384	1,597,265	1,681,420
General and Administrative	104,083	108,507	198,781	205,745
Taxes Other Than Income	194,268	130,114	373,352	260,407
Total	3,273,146	2,484,564	6,079,720	4,987,383
Operating Income	964,931	127,908	1,839,519	235,654
Other Income (Expense), Net	(8,551)	4,972	(7,824)	8,123
Income Before Interest Expense and Income Taxes	956,380	132,880	1,831,695	243,777
Interest Expense
Interest Expense, Net	63,444	70,413	125,400	141,928
Income Before Income Taxes	892,936	62,467	1,706,295	101,849
Income Tax Provision	196,205	39,414	370,975	50,279
Net Income	$ 696,731	$ 23,053	$ 1,335,320	$ 51,570
Net Income Per Share
Basic	$ 1.21	$ 0.04	$ 2.32	$ 0.09
Diluted	1.20	0.04	2.30	0.09
Dividends Declared per Common Share	$ 0.1850	$ 0.1675	$ 0.3700	$ 0.3350
Average Number of Common Shares
Basic	576,135	574,439	575,953	574,162
Diluted	580,375	578,483	580,007	578,573
Other Comprehensive Income (Loss)
Foreign Currency Translation Adjustments	$ (3,229)	$ 1,260	$ 1,773	$ 1,569
Other, Net of Tax	6	(86)	12	(49)
Other Comprehensive Income (Loss)	(3,223)	1,174	1,785	1,520
Comprehensive Income	$ 693,508	$ 24,227	$ 1,337,105	$ 53,090

v3.10.0.1

Consolidated Balance Sheets - USD ($) $ in Thousands	Jun. 30, 2018	Dec. 31, 2017
Current Assets
Cash and Cash Equivalents	$ 1,008,215	$ 834,228
Accounts Receivable, Net	1,907,990	1,597,494
Inventories	670,994	483,865
Assets from Price Risk Management Activities	1,840	7,699
Income Taxes Receivable	364,119	113,357
Other	278,694	242,465
Total	4,231,852	3,279,108
Property, Plant and Equipment
Oil and Gas Properties (Successful Efforts Method)	55,319,050	52,555,741
Other Property, Plant and Equipment	4,141,479	3,960,759
Total Property, Plant and Equipment	59,460,529	56,516,500
Less: Accumulated Depreciation, Depletion and Amortization	(32,306,734)	(30,851,463)
Total Property, Plant and Equipment, Net	27,153,795	25,665,037
Deferred Income Taxes	17,067	17,506
Other Assets	689,666	871,427
Total Assets	32,092,380	29,833,078
Current Liabilities
Accounts Payable	2,336,952	1,847,131
Accrued Taxes Payable	213,461	148,874
Dividends Payable	106,569	96,410
Liabilities from Price Risk Management Activities	195,457	50,429
Current Portion of Long-Term Debt	1,262,540	356,235
Other	182,322	226,463
Total	4,297,301	2,725,542
Long-Term Debt	5,172,257	6,030,836
Other Liabilities	1,304,624	1,275,213
Deferred Income Taxes	3,865,804	3,518,214
Commitments and Contingencies (Note 8)
Stockholders' Equity
Common Stock, $0.01 Par, 1,280,000,000 Shares Authorized and 579,597,990 Shares Issued at June 30, 2018 and 578,827,768 Shares Issued at December 31, 2017	205,796	205,788
Additional Paid in Capital	5,591,643	5,536,547
Accumulated Other Comprehensive Loss	(17,512)	(19,297)
Retained Earnings	11,714,656	10,593,533
Common Stock Held in Treasury, 410,969 Shares at June 30, 2018 and 350,961 Shares at December 31, 2017	(42,189)	(33,298)
Total Stockholders' Equity	17,452,394	16,283,273
Total Liabilities and Stockholders' Equity	$ 32,092,380	$ 29,833,078

v3.10.0.1

Consolidated Balance Sheets (Parenthetical) - $ / shares	Jun. 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)	579,597,990	578,827,768
Treasury Stock (in shares)
Common Stock Held in Treasury, Shares	410,969	350,961

v3.10.0.1

Consolidated Statements of Cash Flows - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017
Cash Flows from Operating Activities
Net Income	$ 1,335,320	$ 51,570
Items Not Requiring (Providing) Cash
Depreciation, Depletion and Amortization	1,597,265	1,681,420
Impairments	116,317	272,121
Stock-Based Compensation Expenses	67,289	58,061
Deferred Income Taxes	347,586	35,162
Losses on Asset Dispositions, Net	(21,286)	(25,674)
Other, Net	13,507	(6,691)
Dry Hole Costs	4,902	27
Mark-to-Market Commodity Derivative Contracts
Total (Gains) Losses	245,654	(71,466)
Net Cash Received from (Payments for) Settlements of Commodity Derivative Contracts	(88,334)	2,591
Other, Net	(261)	(185)
Changes in Components of Working Capital and Other Assets and Liabilities
Accounts Receivable	(309,751)	103,786
Inventories	(192,219)	(6,129)
Accounts Payable	455,977	76,704
Accrued Taxes Payable	22,535	(39,124)
Other Assets	(62,843)	(61,089)
Other Liabilities	(53,168)	(66,869)
Changes in Components of Working Capital Associated with Investing and Financing Activities	(27,279)	(79,138)
Net Cash Provided by Operating Activities	3,493,783	1,976,425
Investing Cash Flows
Additions to Oil and Gas Properties	(2,980,286)	(1,885,417)
Additions to Other Property, Plant and Equipment	(144,858)	(88,076)
Proceeds from Sales of Assets	8,276	175,260
Changes in Components of Working Capital Associated with Investing Activities	27,250	79,138
Net Cash Used in Investing Activities	(3,089,618)	(1,719,095)
Financing Cash Flows
Dividends Paid	(203,610)	(192,984)
Treasury Stock Purchased	(32,023)	(21,678)
Proceeds from Stock Options Exercised and Employee Stock Purchase Plan	11,145	9,608
Repayment of Capital Lease Obligation	(3,354)	(3,251)
Changes in Components of Working Capital Associated with Financing Activities	29	0
Net Cash Used in Financing Activities	(227,813)	(208,305)
Effect of Exchange Rate Changes on Cash	(2,365)	523
Increase in Cash and Cash Equivalents	173,987	49,548
Cash and Cash Equivalents at Beginning of Period	834,228	1,599,895
Cash and Cash Equivalents at End of Period	$ 1,008,215	$ 1,649,443

v3.10.0.1

Summary of Significant Accounting Policies (Notes)	6 Months Ended
	Jun. 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 six months ended June 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 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 six months ended June 30, 2018, were as follows (in thousands):   Three Months Ended   June 30, 2018   Six Months Ended   June 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 $ 2,377,528   $ 2,377,528   $ —   $ 4,478,836   $ 4,478,836   $ — Natural Gas Liquids 286,354   284,898   1,456   507,769   504,543   3,226 Natural Gas 300,845   257,652   43,193   600,611   514,273   86,338 Gathering, Processing and Marketing 1,436,436   1,431,077   5,359   2,538,258   2,527,313   10,945 Total Operating Revenues and Other 4,238,077   4,188,069   50,008   7,919,239   7,818,730   100,509 Operating Expenses                       Gathering and Processing Costs 109,169   64,520   44,649   210,514   120,950   89,564 Marketing Costs 1,420,463   1,415,104   5,359   2,526,853   2,515,908   10,945 Total Operating Expenses 3,273,146   3,223,138   50,008   6,079,720   5,979,211   100,509 Operating Income 964,931   964,931   —   1,839,519   1,839,519   — 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 June 30, 2018, were $1,343 million and $1,608 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. 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, sales of NGLs are recognized when control transfers after processing occurs 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 processing and gathering 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 six months ended June 30, 2018 in accordance with ASU 2018-05. EOG expects to have all provisional amounts finalized by the fourth quarter of 2018. As discussed in EOG's 2017 Annual Report, provisional amounts were recorded for the impact of the statutory rate reduction from 35% to 21% and the deemed repatriation tax on foreign earnings. EOG has not made any measurement period adjustments related to these items during the three and six months ended June 30, 2018, because the foreign earnings and profits study has not been completed and the impact of certain tax elections on EOG's 2017 federal tax filings have not been fully analyzed. Additionally, 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 Internal Revenue Service (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, evaluating certain operational and corporate policies and processes, further defining its population of leases and reviewing numerous contracts. 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. Additionally, EOG 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. EOG does not intend to early-adopt ASU 2016-02 and other related ASUs and has not determined which transition method it will use.

v3.10.0.1

Stock-Based Compensation (Notes)	6 Months Ended
	Jun. 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   June 30,   Six Months Ended   June 30,   2018   2017   2018   2017 Lease and Well $ 11.4   $ 9.6   $ 24.2   $ 20.5 Gathering and Processing Costs 0.1   0.2   0.2   0.4 Exploration Costs 5.7   5.3   12.6   11.5 General and Administrative 14.6   12.5   30.3   25.7 Total $ 31.8   $ 27.6   $ 67.3   $ 58.1 The Amended and Restated EOG Resources, Inc. 2008 Omnibus Equity Compensation Plan (2008 Plan) provides for grants of stock options, stock-settled stock appreciation rights (SARs), restricted stock and restricted stock units, performance units and performance stock and other stock-based awards. At June 30, 2018, approximately 16.9 million common shares remained available for grant under the 2008 Plan. EOG's policy is to issue shares related to the 2008 Plan 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 $11.7 million and $11.1 million during the three months ended June 30, 2018 and 2017, respectively, and $23.7 million and $22.1 million during the six months ended June 30, 2018 and 2017, respectively. Weighted average fair values and valuation assumptions used to value stock option, SAR and ESPP grants during the six-month periods ended June 30, 2018 and 2017 are as follows:   Stock Options/SARs   ESPP   Six Months Ended   June 30,   Six Months Ended   June 30,   2018   2017   2018   2017 Weighted Average Fair Value of Grants $ 29.18   $ 26.64   $ 23.27   $ 24.28 Expected Volatility 28.88 %   30.46 %   22.04 %   30.33 % Risk-Free Interest Rate 2.23 %   1.39 %   1.60 %   0.65 % Dividend Yield 0.67 %   0.68 %   0.66 %   0.69 % Expected Life 5.0 years   5.3 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 six-month periods ended June 30, 2018 and 2017 (stock options and SARs in thousands):   Six Months Ended   June 30, 2018   Six Months Ended   June 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 32   110.17   16   96.41 Exercised (1) (1,662 )   71.33   (783 )   57.05 Forfeited (124 )   92.07   (189 )   89.40 Outstanding at June 30 (2) 7,349   $ 86.71   8,894   $ 76.90 Vested or Expected to Vest (3) 7,006   $ 86.44   8,594   $ 76.53 Exercisable at June 30 (4) 2,938   $ 78.74   4,973   $ 68.43 (1) The total intrinsic value of stock options/SARs exercised for the six months ended June 30, 2018 and 2017 was $74.5 million and $33.5 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 June 30, 2018 and 2017 was $277.2 million and $147.8 million, respectively. At June 30, 2018 and 2017, the weighted average remaining contractual life was 4.3 years and 3.6 years, respectively. (3) The total intrinsic value of stock options/SARs vested or expected to vest at June 30, 2018 and 2017 was $266.2 million and $145.7 million, respectively. At June 30, 2018 and 2017, the weighted average remaining contractual life was 4.3 years and 3.5 years, respectively. (4) The total intrinsic value of stock options/SARs exercisable at June 30, 2018 and 2017 was $134.2 million and $120.9 million, respectively. At June 30, 2018 and 2017, the weighted average remaining contractual life was 2.7 years and 2.2 years, respectively. At June 30, 2018, unrecognized compensation expense related to non-vested stock option, SAR and ESPP grants totaled $76.9 million. Such unrecognized expense will be amortized on a straight-line basis over a weighted average period of 1.9 years. Restricted Stock and Restricted Stock Units. Employees may be granted restricted (non-vested) stock and/or restricted stock units without cost to them. Stock-based compensation expense related to restricted stock and restricted stock units totaled $19.0 million and $15.6 million for the three months ended June 30, 2018 and 2017, respectively, and $41.3 million and $34.2 million for the six months ended June 30, 2018 and 2017, respectively. The following table sets forth restricted stock and restricted stock unit transactions for the six-month periods ended June 30, 2018 and 2017 (shares and units in thousands):   Six Months Ended   June 30, 2018   Six Months Ended   June 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 309   103.52   437   98.97 Released (1) (331 )   69.55   (407 )   63.20 Forfeited (120 )   91.28   (143 )   83.92 Outstanding at June 30 (2) 3,763   $ 91.39   3,849   $ 83.40 (1) The total intrinsic value of restricted stock and restricted stock units released for the six months ended June 30, 2018 and 2017 was $34.9 million and $40.4 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 June 30, 2018 and 2017 was $468.2 million and $348.4 million, respectively. At June 30, 2018, unrecognized compensation expense related to restricted stock and restricted stock units totaled $153.2 million. Such unrecognized expense will be amortized on a straight-line basis over a weighted average period of 2.1 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 $1.1 million and $0.9 million for the three-month periods ended June 30, 2018 and 2017, respectively, and $2.3 million and $1.8 million for the six-month periods ended June 30, 2018 and 2017, respectively. The following table sets forth the Performance Awards transactions for the six-month periods ended June 30, 2018 and 2017:   Six Months Ended   June 30, 2018   Six Months Ended   June 30, 2017   Number of Units   Weighted Average Price per Grant Date   Number of Units   Weighted Average Price per Grant Date Outstanding at January 1 502,331   $ 90.96   545,290   $ 80.92 Granted —   —   —   — Granted for Performance Multiple (1) 71,805   101.87   118,834   84.43 Released (2) —   —   (89,224 )   84.43 Forfeited —   —   —   — Outstanding at June 30 (3) 574,136 (4) $ 92.33   574,900   $ 81.10 (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 six months ended June 30, 2017 was approximately $9.0 million. 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 June 30, 2018 and 2017 was approximately $71.4 million and $52.0 million, respectively. (4) Upon the application of the relevant performance multiple at the completion of each of the remaining Performance Periods, a minimum of 292,054 and a maximum of 856,218 Performance Awards could be outstanding. At June 30, 2018, unrecognized compensation expense related to Performance Awards totaled $6.0 million. Such unrecognized expense will be amortized on a straight-line basis over a weighted average period of 1.5 years.

v3.10.0.1

Net Income Per Share (Notes)	6 Months Ended
	Jun. 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 six-month periods ended June 30, 2018 and 2017 (in thousands, except per share data):   Three Months Ended   June 30,   Six Months Ended   June 30,   2018   2017   2018   2017 Numerator for Basic and Diluted Earnings Per Share -               Net Income $ 696,731   $ 23,053   $ 1,335,320   $ 51,570 Denominator for Basic Earnings Per Share -               Weighted Average Shares 576,135   574,439   575,953   574,162 Potential Dilutive Common Shares -               Stock Options/SARs 1,365   1,452   1,237   1,669 Restricted Stock/Units and Performance Units/Stock 2,875   2,592   2,817   2,742 Denominator for Diluted Earnings Per Share -               Adjusted Diluted Weighted Average Shares 580,375   578,483   580,007   578,573 Net Income Per Share               Basic $ 1.21   $ 0.04   $ 2.32   $ 0.09 Diluted $ 1.20   $ 0.04   $ 2.30   $ 0.09 The diluted earnings per share calculation excludes stock options, SARs, restricted stock and units and performance units that were anti-dilutive. Shares underlying the excluded stock options and SARs were zero and 3.4 million shares for the three months ended June 30, 2018 and 2017, respectively, and were zero and 2.0 million shares, respectively, for the six months ended June 30, 2018 and 2017, respectively.

v3.10.0.1

Supplemental Cash Flow Information (Notes)	6 Months Ended
	Jun. 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 six-month periods ended June 30, 2018 and 2017 (in thousands):   Six Months Ended   June 30,   2018   2017 Interest (1) $ 133,148   $ 136,733 Income Taxes, Net of Refunds Received $ 62,777   $ 98,157 (1) Net of capitalized interest of $11 million and $14 million for the six months ended June 30, 2018 and 2017, respectively. EOG's accrued capital expenditures at June 30, 2018 and 2017 were $724 million and $488 million, respectively. Non-cash investing activities for the six months ended June 30, 2018, included additions of $83 million to EOG's oil and gas properties as a result of property exchanges and an addition of $48 million to EOG's other property, plant and equipment in connection with a capital lease transaction in the Permian Basin. Non-cash investing activities for the six months ended June 30, 2017, included additions of $154 million to EOG's oil and gas properties as a result of property exchanges.

v3.10.0.1

Segment Information (Notes)	6 Months Ended
	Jun. 30, 2018
Segment Reporting [Abstract]
Segment Information	Segment Information Selected financial information by reportable segment is presented below for the three-month and six-month periods ended June 30, 2018 and 2017 (in thousands):   Three Months Ended   June 30,   Six Months Ended   June 30,   2018   2017   2018   2017 Operating Revenues and Other               United States $ 4,114,610   $ 2,530,885   $ 7,685,744   $ 5,050,734 Trinidad 81,611   72,299   162,624   146,222 Other International (1) 41,856   9,288   70,871   26,081 Total $ 4,238,077   $ 2,612,472   $ 7,919,239   $ 5,223,037 Operating Income (Loss)               United States $ 946,883   $ 130,314   $ 1,792,736   $ 249,845 Trinidad 27,821   32,360   68,118   48,773 Other International (1) (9,773 )   (34,766 )   (21,335 )   (62,964 ) Total 964,931   127,908   1,839,519   235,654 Reconciling Items               Other Income (Expense), Net (8,551 )   4,972   (7,824 )   8,123 Interest Expense, Net (63,444 )   (70,413 )   (125,400 )   (141,928 ) Income Before Income Taxes $ 892,936   $ 62,467   $ 1,706,295   $ 101,849 (1) Other International primarily consists of EOG's United Kingdom, China and Canada operations. Total assets by reportable segment are presented below at June 30, 2018 and December 31, 2017 (in thousands):   At June 30, 2018   At December 31, 2017 Total Assets       United States $ 31,114,907   $ 28,312,599 Trinidad 624,358   974,477 Other International (1) 353,115   546,002 Total $ 32,092,380   $ 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)	6 Months Ended
	Jun. 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 six-month periods ended June 30, 2018 and 2017 (in thousands):   Six Months Ended   June 30,   2018   2017 Carrying Amount at January 1 $ 946,848   $ 912,926 Liabilities Incurred 25,496   19,276 Liabilities Settled (1) (8,184 )   (28,726 ) Accretion 17,941   17,010 Revisions (148 )   3,646 Foreign Currency Translations (547 )   3,808 Carrying Amount at June 30 $ 981,406   $ 927,940         Current Portion $ 18,892   $ 33,922 Noncurrent Portion $ 962,514   $ 894,018 (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)	6 Months Ended
	Jun. 30, 2018
Capitalized Exploratory Well Costs [Abstract]
Exploratory Well Costs	Exploratory Well Costs EOG's net changes in capitalized exploratory well costs for the six-month period ended June 30, 2018, are presented below (in thousands):   Six Months Ended   June 30, 2018 Balance at January 1 $ 2,167 Additions Pending the Determination of Proved Reserves 3,512 Reclassifications to Proved Properties (5,250 ) Costs Charged to Expense (429 ) Balance at June 30 $ — At June 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)	6 Months Ended
	Jun. 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)	6 Months Ended
	Jun. 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 six months ended June 30, 2018 and 2017, EOG's total costs recognized for these pension plans were $20.2 million and $18.4 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)	6 Months Ended
	Jun. 30, 2018
Debt Disclosure [Abstract]
Long-Term Debt and Common Stock	Long-Term Debt and Common Stock Long-Term Debt. During the six months ended June 30, 2018, EOG utilized commercial paper borrowings, bearing market interest rates, for various corporate financing purposes. EOG did not utilize any such borrowings during the six months ended June 30, 2017. At June 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 $17 million and zero during the six months ended June 30, 2018 and 2017, respectively. The weighted average interest rate for commercial paper borrowings during the six months ended June 30, 2018, was 1.97%. 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 June 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 June 30, 2018, would have been 3.09% and 5.00%, 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)	6 Months Ended
	Jun. 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 June 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 June 30, 2018               Financial Assets:               Natural Gas Swaps $ —   $ —   $ —   $ — Natural Gas Options —   2   —   2 Crude Oil Basis Swaps —   83   —   83 Financial Liabilities:               Crude Oil Swaps $ —   $ 261   $ —   $ 261                 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 $163 million were written down to their fair value of $131 million, resulting in pretax impairment charges of $32 million for the six months ended June 30, 2018. Included in the $32 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 as the basis for determining the fair value of unproved properties received in non-cash property exchanges. See Note 4. Fair Value of Debt. At June 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 $6,419 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)	6 Months Ended
	Jun. 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 six months ended June 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 July 31, 2018 (closed)   15,000   $ 1.063   August 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 six months ended June 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 July 31, 2018 (closed)   37,000   $ 3.818   August 1, 2018 through December 31, 2018   37,000   3.818               2019           January 1, 2019 through December 31, 2019   8,000   $ 5.660 Presented below is a comprehensive summary of EOG's crude oil price swap contracts for the six months ended June 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 June 30, 2018 (closed)   134,000   $ 60.04 July 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 six months ended June 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 July 31, 2018 (closed)   35,000   $ 3.00 August 1, 2018 through November 30, 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 six months ended June 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 July 31, 2018 (closed) 120,000   $ 3.38   96,000   $ 2.94 August 1, 2018 through November 30, 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 June 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   June 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   17   — Liability Derivatives             Crude oil and natural gas derivative contracts -             Current portion   Liabilities from Price Risk Management Activities (1)   $ 195   $ 50 Noncurrent portion   Other Liabilities   —   7 (1) The current portion of Liabilities from Price Risk Management Activities consists of gross liabilities of $261 million, partially offset by gross assets of $66 million at June 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 June 30, 2018 and December 31, 2017. EOG had no collateral posted and held no collateral at June 30, 2018 and December 31, 2017.

v3.10.0.1

Acquisitions and Divestitures (Notes)	6 Months Ended
	Jun. 30, 2018
Discontinued Operations and Disposal Groups [Abstract]
Acquisitions and Divestitures	Acquisitions and Divestitures During the six months ended June 30, 2018, EOG recognized a net loss on asset dispositions of $(21) million, primarily due to non-cash exchanges of unproved leasehold in New Mexico and Wyoming as well as the disposition of inventory and other assets, and received proceeds of approximately $8 million. During the six months ended June 30, 2017, EOG recognized a net loss on asset dispositions of $(26) million and received proceeds of approximately $175 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)	6 Months Ended
	Jun. 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 six months ended June 30, 2018, were as follows (in thousands):   Three Months Ended   June 30, 2018   Six Months Ended   June 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 $ 2,377,528   $ 2,377,528   $ —   $ 4,478,836   $ 4,478,836   $ — Natural Gas Liquids 286,354   284,898   1,456   507,769   504,543   3,226 Natural Gas 300,845   257,652   43,193   600,611   514,273   86,338 Gathering, Processing and Marketing 1,436,436   1,431,077   5,359   2,538,258   2,527,313   10,945 Total Operating Revenues and Other 4,238,077   4,188,069   50,008   7,919,239   7,818,730   100,509 Operating Expenses                       Gathering and Processing Costs 109,169   64,520   44,649   210,514   120,950   89,564 Marketing Costs 1,420,463   1,415,104   5,359   2,526,853   2,515,908   10,945 Total Operating Expenses 3,273,146   3,223,138   50,008   6,079,720   5,979,211   100,509 Operating Income 964,931   964,931   —   1,839,519   1,839,519   —

v3.10.0.1

Stock-Based Compensation (Tables)	6 Months Ended
	Jun. 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   June 30,   Six Months Ended   June 30,   2018   2017   2018   2017 Lease and Well $ 11.4   $ 9.6   $ 24.2   $ 20.5 Gathering and Processing Costs 0.1   0.2   0.2   0.4 Exploration Costs 5.7   5.3   12.6   11.5 General and Administrative 14.6   12.5   30.3   25.7 Total $ 31.8   $ 27.6   $ 67.3   $ 58.1
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 six-month periods ended June 30, 2018 and 2017 are as follows:   Stock Options/SARs   ESPP   Six Months Ended   June 30,   Six Months Ended   June 30,   2018   2017   2018   2017 Weighted Average Fair Value of Grants $ 29.18   $ 26.64   $ 23.27   $ 24.28 Expected Volatility 28.88 %   30.46 %   22.04 %   30.33 % Risk-Free Interest Rate 2.23 %   1.39 %   1.60 %   0.65 % Dividend Yield 0.67 %   0.68 %   0.66 %   0.69 % Expected Life 5.0 years   5.3 years   0.5 years   0.5 years
Stock Options and SARs Transactions	The following table sets forth stock option and SAR transactions for the six-month periods ended June 30, 2018 and 2017 (stock options and SARs in thousands):   Six Months Ended   June 30, 2018   Six Months Ended   June 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 32   110.17   16   96.41 Exercised (1) (1,662 )   71.33   (783 )   57.05 Forfeited (124 )   92.07   (189 )   89.40 Outstanding at June 30 (2) 7,349   $ 86.71   8,894   $ 76.90 Vested or Expected to Vest (3) 7,006   $ 86.44   8,594   $ 76.53 Exercisable at June 30 (4) 2,938   $ 78.74   4,973   $ 68.43 (1) The total intrinsic value of stock options/SARs exercised for the six months ended June 30, 2018 and 2017 was $74.5 million and $33.5 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 June 30, 2018 and 2017 was $277.2 million and $147.8 million, respectively. At June 30, 2018 and 2017, the weighted average remaining contractual life was 4.3 years and 3.6 years, respectively. (3) The total intrinsic value of stock options/SARs vested or expected to vest at June 30, 2018 and 2017 was $266.2 million and $145.7 million, respectively. At June 30, 2018 and 2017, the weighted average remaining contractual life was 4.3 years and 3.5 years, respectively. (4) The total intrinsic value of stock options/SARs exercisable at June 30, 2018 and 2017 was $134.2 million and $120.9 million, respectively. At June 30, 2018 and 2017, the weighted average remaining contractual life was 2.7 years and 2.2 years, respectively.
Restricted Stock and Restricted Stock Unit Transactions	The following table sets forth restricted stock and restricted stock unit transactions for the six-month periods ended June 30, 2018 and 2017 (shares and units in thousands):   Six Months Ended   June 30, 2018   Six Months Ended   June 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 309   103.52   437   98.97 Released (1) (331 )   69.55   (407 )   63.20 Forfeited (120 )   91.28   (143 )   83.92 Outstanding at June 30 (2) 3,763   $ 91.39   3,849   $ 83.40 (1) The total intrinsic value of restricted stock and restricted stock units released for the six months ended June 30, 2018 and 2017 was $34.9 million and $40.4 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 June 30, 2018 and 2017 was $468.2 million and $348.4 million, respectively.
Weighted Average Fair Values and Valuation Assumptions for Performance Award Grants	The following table sets forth the Performance Awards transactions for the six-month periods ended June 30, 2018 and 2017:   Six Months Ended   June 30, 2018   Six Months Ended   June 30, 2017   Number of Units   Weighted Average Price per Grant Date   Number of Units   Weighted Average Price per Grant Date Outstanding at January 1 502,331   $ 90.96   545,290   $ 80.92 Granted —   —   —   — Granted for Performance Multiple (1) 71,805   101.87   118,834   84.43 Released (2) —   —   (89,224 )   84.43 Forfeited —   —   —   — Outstanding at June 30 (3) 574,136 (4) $ 92.33   574,900   $ 81.10 (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 six months ended June 30, 2017 was approximately $9.0 million. 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 June 30, 2018 and 2017 was approximately $71.4 million and $52.0 million, respectively. (4) Upon the application of the relevant performance multiple at the completion of each of the remaining Performance Periods, a minimum of 292,054 and a maximum of 856,218 Performance Awards could be outstanding.

v3.10.0.1

Net Income Per Share (Tables)	6 Months Ended
	Jun. 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 six-month periods ended June 30, 2018 and 2017 (in thousands, except per share data):   Three Months Ended   June 30,   Six Months Ended   June 30,   2018   2017   2018   2017 Numerator for Basic and Diluted Earnings Per Share -               Net Income $ 696,731   $ 23,053   $ 1,335,320   $ 51,570 Denominator for Basic Earnings Per Share -               Weighted Average Shares 576,135   574,439   575,953   574,162 Potential Dilutive Common Shares -               Stock Options/SARs 1,365   1,452   1,237   1,669 Restricted Stock/Units and Performance Units/Stock 2,875   2,592   2,817   2,742 Denominator for Diluted Earnings Per Share -               Adjusted Diluted Weighted Average Shares 580,375   578,483   580,007   578,573 Net Income Per Share               Basic $ 1.21   $ 0.04   $ 2.32   $ 0.09 Diluted $ 1.20   $ 0.04   $ 2.30   $ 0.09

v3.10.0.1

Supplemental Cash Flow Information (Tables)	6 Months Ended
	Jun. 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 six-month periods ended June 30, 2018 and 2017 (in thousands):   Six Months Ended   June 30,   2018   2017 Interest (1) $ 133,148   $ 136,733 Income Taxes, Net of Refunds Received $ 62,777   $ 98,157 (1) Net of capitalized interest of $11 million and $14 million for the six months ended June 30, 2018 and 2017, respectively.

v3.10.0.1

Segment Information (Tables)	6 Months Ended
	Jun. 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 six-month periods ended June 30, 2018 and 2017 (in thousands):   Three Months Ended   June 30,   Six Months Ended   June 30,   2018   2017   2018   2017 Operating Revenues and Other               United States $ 4,114,610   $ 2,530,885   $ 7,685,744   $ 5,050,734 Trinidad 81,611   72,299   162,624   146,222 Other International (1) 41,856   9,288   70,871   26,081 Total $ 4,238,077   $ 2,612,472   $ 7,919,239   $ 5,223,037 Operating Income (Loss)               United States $ 946,883   $ 130,314   $ 1,792,736   $ 249,845 Trinidad 27,821   32,360   68,118   48,773 Other International (1) (9,773 )   (34,766 )   (21,335 )   (62,964 ) Total 964,931   127,908   1,839,519   235,654 Reconciling Items               Other Income (Expense), Net (8,551 )   4,972   (7,824 )   8,123 Interest Expense, Net (63,444 )   (70,413 )   (125,400 )   (141,928 ) Income Before Income Taxes $ 892,936   $ 62,467   $ 1,706,295   $ 101,849 (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 June 30, 2018 and December 31, 2017 (in thousands):   At June 30, 2018   At December 31, 2017 Total Assets       United States $ 31,114,907   $ 28,312,599 Trinidad 624,358   974,477 Other International (1) 353,115   546,002 Total $ 32,092,380   $ 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)	6 Months Ended
	Jun. 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 six-month periods ended June 30, 2018 and 2017 (in thousands):   Six Months Ended   June 30,   2018   2017 Carrying Amount at January 1 $ 946,848   $ 912,926 Liabilities Incurred 25,496   19,276 Liabilities Settled (1) (8,184 )   (28,726 ) Accretion 17,941   17,010 Revisions (148 )   3,646 Foreign Currency Translations (547 )   3,808 Carrying Amount at June 30 $ 981,406   $ 927,940         Current Portion $ 18,892   $ 33,922 Noncurrent Portion $ 962,514   $ 894,018 (1) Includes settlements related to asset sales.

v3.10.0.1

Exploratory Well Costs (Tables)	6 Months Ended
	Jun. 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 six-month period ended June 30, 2018, are presented below (in thousands):   Six Months Ended   June 30, 2018 Balance at January 1 $ 2,167 Additions Pending the Determination of Proved Reserves 3,512 Reclassifications to Proved Properties (5,250 ) Costs Charged to Expense (429 ) Balance at June 30 $ —

v3.10.0.1

Fair Value Measurements (Tables)	6 Months Ended
	Jun. 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 June 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 June 30, 2018               Financial Assets:               Natural Gas Swaps $ —   $ —   $ —   $ — Natural Gas Options —   2   —   2 Crude Oil Basis Swaps —   83   —   83 Financial Liabilities:               Crude Oil Swaps $ —   $ 261   $ —   $ 261                 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)	6 Months Ended
	Jun. 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 June 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   June 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   17   — Liability Derivatives             Crude oil and natural gas derivative contracts -             Current portion   Liabilities from Price Risk Management Activities (1)   $ 195   $ 50 Noncurrent portion   Other Liabilities   —   7 (1) The current portion of Liabilities from Price Risk Management Activities consists of gross liabilities of $261 million, partially offset by gross assets of $66 million at June 30, 2018, and gross liabilities of $55 million, partially offset by gross assets of $5 million at December 31, 2017.
Crude Oil [Member] | Midland Differential Basis Swaps [Member]
Derivatives, Fair Value [Line Items]
Schedule of Derivative Instruments	Presented below is a comprehensive summary of EOG's Midland Differential basis swap contracts for the six months ended June 30, 2018. The weighted average price differential expressed in dollars per barrel ($/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 July 31, 2018 (closed)   15,000   $ 1.063   August 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 six months ended June 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 July 31, 2018 (closed)   37,000   $ 3.818   August 1, 2018 through December 31, 2018   37,000   3.818               2019           January 1, 2019 through December 31, 2019   8,000   $ 5.660
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 six months ended June 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 June 30, 2018 (closed)   134,000   $ 60.04 July 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 six months ended June 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 July 31, 2018 (closed)   35,000   $ 3.00 August 1, 2018 through November 30, 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 six months ended June 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 July 31, 2018 (closed) 120,000   $ 3.38   96,000   $ 2.94 August 1, 2018 through November 30, 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		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017	Jan. 01, 2018
Crude Oil and Condensate	$ 2,377,528	$ 1,445,454	$ 4,478,836	$ 2,875,515
Natural Gas Liquids	286,354	146,907	507,769	300,351
Natural Gas	300,845	224,008	600,611	454,610
Gathering, Processing and Marketing	1,436,436	778,797	2,538,258	1,505,334
Total Operating Revenues and Other	4,238,077	2,612,472	7,919,239	5,223,037
Gathering and Processing Costs	109,169		210,514
Marketing Costs	1,420,463	790,599	2,526,853	1,527,135
Total Operating Expenses	3,273,146	2,484,564	6,079,720	4,987,383
Operating Income (Loss)	964,931	$ 127,908	1,839,519	$ 235,654
Accounts Receivable From Contracts With Customers	1,608,000		1,608,000		$ 1,343,000
Amounts Without Adoption of ASU 2014-09 [Member]
Crude Oil and Condensate	2,377,528		4,478,836
Natural Gas Liquids	284,898		504,543
Natural Gas	257,652		514,273
Gathering, Processing and Marketing	1,431,077		2,527,313
Total Operating Revenues and Other	4,188,069		7,818,730
Gathering and Processing Costs	64,520		120,950
Marketing Costs	1,415,104		2,515,908
Total Operating Expenses	3,223,138		5,979,211
Operating Income (Loss)	964,931		1,839,519
Effect of Change [Member]
Crude Oil and Condensate	0		0
Natural Gas Liquids	1,456		3,226
Natural Gas	43,193		86,338
Gathering, Processing and Marketing	5,359		10,945
Total Operating Revenues and Other	50,008		100,509
Gathering and Processing Costs	44,649		89,564
Marketing Costs	5,359		10,945
Total Operating Expenses	50,008		100,509
Operating Income (Loss)	$ 0		$ 0

v3.10.0.1

Stock-Based Compensation (Details) - USD ($) $ / shares in Units, $ in Thousands		3 Months Ended			6 Months Ended
		Jun. 30, 2018		Jun. 30, 2017	Jun. 30, 2018		Jun. 30, 2017
Stock Options/SARs and Employee Stock Purchase Plan (ESPP) Disclosures [Line Items]
Total Operating Expenses		$ 3,273,146		$ 2,484,564	$ 6,079,720		$ 4,987,383
Compensation expense related to the company's stock-based compensation plans		$ 31,800		27,600	$ 67,300		58,100
Common Shares Available for Grant		16,900,000			16,900,000
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		$ 11,700		$ 11,100	$ 23,700		$ 22,100
Unrecognized compensation expense		$ 76,900			$ 76,900
Weighted average period over which unrecognized compensation expense will be recognized (in years)					1 year 10 months 24 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)					$ 29.18		$ 26.64
Expected Volatility (in hundredths)					28.88%		30.46%
Risk-Free Interest Rate (in hundredths)					2.23%		1.39%
Dividend Yield (in hundredths)					0.67%		0.68%
Expected Life (in years)					5 years		5 years 3 months 18 days
Stock Options and SARs Rollforward [Abstract]
Outstanding at January 1 (in shares)					9,103,000		9,850,000
Granted (in shares)					32,000		16,000
Exercised (1) (in shares)	[1]				(1,662,000)		(783,000)
Forfeited (in shares)					(124,000)		(189,000)
Outstanding at June 30 (2) (in shares)	[2]	7,349,000		8,894,000	7,349,000		8,894,000
Stock Options and SARs Vested or Expected to Vest (in shares)	[3]	7,006,000		8,594,000	7,006,000		8,594,000
Stock Options and SARs Exercisable at September 30 (in shares)	[4]	2,938,000		4,973,000	2,938,000		4,973,000
Intrinsic Value of Stock Options/SARs Exercised					$ 74,500		$ 33,500
Intrinsic Value of Stock Options/SARs Outstanding		$ 277,200		$ 147,800	$ 277,200		$ 147,800
Weighted Average Remaining Contractual Life for Stock Options/SARs Outstanding					4 years 3 months 18 days		3 years 7 months 6 days
Intrinsic Value of Stock Options/SARs Vested or Expected to Vest		266,200		145,700	$ 266,200		$ 145,700
Weighted average remaining contractual life for stock options/SARs vested or expected to vest (in years)al Term					4 years 3 months 18 days		3 years 6 months
Aggregate Intrinsic Value for Exercisable Units		$ 134,200		$ 120,900	$ 134,200		$ 120,900
Weighted average remaining contractual life for exercisable options/SARs (in years)					2 years 8 months 12 days		2 years 2 months 12 days
Weighted Average Grant Price Stock Option and SARs [Rollforward]
Outstanding at January 1 (price per share)					$ 83.89		$ 75.53
Granted (price per share)					110.17		96.41
Exercised (1) (price per share)	[1]				71.33		57.05
Forfeited (price per share)					92.07		89.40
Outstanding at June 30 (2) (price per share)	[2]	$ 86.71		$ 76.90	86.71		76.90
Vested or Expected to Vest (3) (price per share)	[3]	86.44		76.53	86.44		76.53
Exercisable at June 30 (4) (price per share)	[4]	$ 78.74		$ 68.43	78.74		68.43
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)					$ 23.27		$ 24.28
Expected Volatility (in hundredths)					22.04%		30.33%
Risk-Free Interest Rate (in hundredths)					1.60%		0.65%
Dividend Yield (in hundredths)					0.66%		0.69%
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		$ 153,200			$ 153,200
Weighted average period over which unrecognized compensation expense will be recognized (in years)					2 years 1 month 6 days
Intrinsic value released during the year					$ 34,900		$ 40,400
Aggregate intrinsic value of stock and units outstanding		468,200		$ 348,400	468,200		348,400
Restricted Stock/Restricted Stock Units [Roll Forward]
Share-Based Compensation Arrangement By Restricted Stock And Restricted Stock Units Compensation Cost		$ 19,000		$ 15,600	$ 41,300		$ 34,200
Outstanding at January 1 (in shares)					3,905,000		3,962,000
Granted (in shares)					309,000		437,000
Released (1) (in shares)	[5]				(331,000)		(407,000)
Forfeited (in shares)					(120,000)		(143,000)
Outstanding at June 30 (2) (in shares)	[6]	3,763,000		3,849,000	3,763,000		3,849,000
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)					103.52		98.97
Released (1) (price per share)	[5]				69.55		63.20
Forfeited (price per share)					91.28		83.92
Outstanding at June 30 (2) (price per share)	[6]	$ 91.39		$ 83.40	$ 91.39		$ 83.40
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		$ 1,100		$ 900	$ 2,300		$ 1,800
Unrecognized compensation expense		6,000			$ 6,000
Weighted average period over which unrecognized compensation expense will be recognized (in years)					1 year 6 months
Intrinsic value released during the year					$ 9,000
Aggregate intrinsic value of stock and units outstanding		$ 71,400		$ 52,000	$ 71,400		$ 52,000
Minimum Performance Units and Stock Allowed to be Outstanding					292,054
Maximum Performance Units and Stock Allowed to be Outstanding					856,218
Restricted Stock/Restricted Stock Units [Roll Forward]
Outstanding at January 1 (in shares)					502,331		545,290
Granted (in shares)					0		0
Granted for Performance Multiple (1)	[7]				71,805		118,834
Released (1) (in shares)					0		89,224	[8]
Forfeited (in shares)					0		0
Outstanding at June 30 (2) (in shares)	[9]	574,136	[10]	574,900	574,136	[10]	574,900
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)					0.00		0.00
Granted for Performance Multiple (1) (in dollars per share)	[7]				101.87		84.43
Released (1) (price per share)	[8]				0.00		84.43
Forfeited (price per share)					0.00		0.00
Outstanding at June 30 (2) (price per share)	[9]	$ 92.33		$ 81.10	$ 92.33		$ 81.10
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 [Member]
Stock Options/SARs and Employee Stock Purchase Plan (ESPP) Disclosures [Line Items]
Compensation expense related to the company's stock-based compensation plans		$ 11,400		$ 9,600	$ 24,200		$ 20,500
Gathering And Processing Costs [Member]
Stock Options/SARs and Employee Stock Purchase Plan (ESPP) Disclosures [Line Items]
Compensation expense related to the company's stock-based compensation plans		100		200	200		400
Exploration Costs [Member]
Stock Options/SARs and Employee Stock Purchase Plan (ESPP) Disclosures [Line Items]
Compensation expense related to the company's stock-based compensation plans		5,700		5,300	12,600		11,500
General And Administrative [Member]
Stock Options/SARs and Employee Stock Purchase Plan (ESPP) Disclosures [Line Items]
Compensation expense related to the company's stock-based compensation plans		$ 14,600		$ 12,500	$ 30,300		$ 25,700
[1] The total intrinsic value of stock options/SARs exercised for the six months ended June 30, 2018 and 2017 was $74.5 million and $33.5 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 June 30, 2018 and 2017 was $277.2 million and $147.8 million, respectively. At June 30, 2018 and 2017, the weighted average remaining contractual life was 4.3 years and 3.6 years, respectively. [3] The total intrinsic value of stock options/SARs vested or expected to vest at June 30, 2018 and 2017 was $266.2 million and $145.7 million, respectively. At June 30, 2018 and 2017, the weighted average remaining contractual life was 4.3 years and 3.5 years, respectively. [4] The total intrinsic value of stock options/SARs exercisable at June 30, 2018 and 2017 was $134.2 million and $120.9 million, respectively. At June 30, 2018 and 2017, the weighted average remaining contractual life was 2.7 years and 2.2 years, respectively. [5] The total intrinsic value of restricted stock and restricted stock units released for the six months ended June 30, 2018 and 2017 was $34.9 million and $40.4 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 June 30, 2018 and 2017 was $468.2 million and $348.4 million, respectively. [7] 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. [8] The total intrinsic value of Performance Awards released during the six months ended June 30, 2017 was approximately $9.0 million. [9] The total intrinsic value of Performance Awards outstanding at June 30, 2018 and 2017 was approximately $71.4 million and $52.0 million, respectively. [10] Upon the application of the relevant performance multiple at the completion of each of the remaining Performance Periods, a minimum of 292,054 and a maximum of 856,218 Performance Awards could be outstanding.

v3.10.0.1

Net Income Per Share (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Numerator for Basic and Diluted Earnings Per Share - [Abstract]
Net Income	$ 696,731	$ 23,053	$ 1,335,320	$ 51,570
Denominator for Basic Earnings Per Share - [Abstract]
Weighted Average Shares	576,135	574,439	575,953	574,162
Denominator for Diluted Earnings Per Share - [Abstract]
Adjusted Diluted Weighted Average Shares	580,375	578,483	580,007	578,573
Antidilutive Securities Excluded from Computation of Earnings Per Share [Abstract]
Anti-dilutive Securities excluded from Diluted Earnings Per Share Calculation	0	3,400	0	2,000
Net Income Per Share
Basic	$ 1.21	$ 0.04	$ 2.32	$ 0.09
Diluted	$ 1.20	$ 0.04	$ 2.30	$ 0.09
Stock Options And SARs [Member]
Potential Dilutive Common Shares - [Abstract]
Common Shares Attributable to Dilutive Effect of Share-Based Payment Arrangments	1,365	1,452	1,237	1,669
Restricted Stock/Units and Performance Units/Stock [Member]
Potential Dilutive Common Shares - [Abstract]
Common Shares Attributable to Dilutive Effect of Share-Based Payment Arrangments	2,875	2,592	2,817	2,742

v3.10.0.1

Supplemental Cash Flow Information (Details) - USD ($) $ in Thousands		6 Months Ended
		Jun. 30, 2018	Jun. 30, 2017
Supplemental Cash Flow Information [Abstract]
Interest (1)	[1]	$ 133,148	$ 136,733
Income Taxes, Net of Refunds Received		62,777	98,157
Interest Costs Capitalized		11,000	14,000
Accrued Capital Expenditures		724,000	488,000
Non-Cash Property Exchanges		83,000	$ 154,000
Non-Cash Other Property, Plant and Equipment		$ 48,000
[1] Net of capitalized interest of $11 million and $14 million for the six months ended June 30, 2018 and 2017, respectively.

v3.10.0.1

Segment Information (Details) - USD ($) $ in Thousands		3 Months Ended		6 Months Ended
		Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017	Dec. 31, 2017
Schedule of Segment Reporting Information By Segment [Abstract]
Operating Revenues and Other		$ 4,238,077	$ 2,612,472	$ 7,919,239	$ 5,223,037
Operating Income (Loss)		964,931	127,908	1,839,519	235,654
Other Income (Expense), Net		(8,551)	4,972	(7,824)	8,123
Interest Expense, Net		63,444	70,413	125,400	141,928
Income Before Income Taxes		892,936	62,467	1,706,295	101,849
Total Assets		32,092,380		32,092,380		$ 29,833,078
United States [Member]
Schedule of Segment Reporting Information By Segment [Abstract]
Operating Revenues and Other		4,114,610	2,530,885	7,685,744	5,050,734
Operating Income (Loss)		946,883	130,314	1,792,736	249,845
Total Assets		31,114,907		31,114,907		28,312,599
Trinidad [Member]
Schedule of Segment Reporting Information By Segment [Abstract]
Operating Revenues and Other		81,611	72,299	162,624	146,222
Operating Income (Loss)		27,821	32,360	68,118	48,773
Total Assets		624,358		624,358		974,477
Other International [Member]
Schedule of Segment Reporting Information By Segment [Abstract]
Operating Revenues and Other	[1]	41,856	9,288	70,871	26,081
Operating Income (Loss)	[1]	(9,773)	$ (34,766)	(21,335)	$ (62,964)
Total Assets	[1]	$ 353,115		$ 353,115		$ 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		6 Months Ended
		Jun. 30, 2018	Jun. 30, 2017
Asset Retirement Obligation [Abstract]
Carrying Amount at January 1		$ 946,848	$ 912,926
Liabilities Incurred		25,496	19,276
Liabilities Settled (1)	[1]	(8,184)	(28,726)
Accretion		17,941	17,010
Revisions		(148)	3,646
Foreign Currency Translations		(547)	3,808
Carrying Amount at March 31		981,406	927,940
Current Portion		18,892	33,922
Noncurrent Portion		$ 962,514	$ 894,018
[1] Includes settlements related to asset sales.

v3.10.0.1

Exploratory Well Costs (Details) $ in Thousands	6 Months Ended
	Jun. 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	3,512
Reclassifications to Proved Properties	(5,250)
Costs Charged to Expense	(429)
Balance at June 30	$ 0

v3.10.0.1

Pension and Postretirement Benefits (Details) - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017
Defined Benefit and Defined Contribution Plan Disclosure [Line Items]
Total Pension Plans Costs	$ 20.2	$ 18.4

v3.10.0.1

Long-Term Debt and Common Stock (Details) - USD ($)	6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Dec. 31, 2017
Debt Instrument [Abstract]
Dividends Common Stock Declared	$ 0.1850
Dividends Payable, Amount Per Share After Increase	$ 0.22
Line of Credit Facility [Line Items]
Weighted average interest rate (in hundredths)	1.97%
Commercial Paper [Member]
Line of Credit Facility [Line Items]
Borrowings Outstanding	$ 0		$ 0
Average Outstanding Amount	17,000,000	$ 0
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)	3.09%
Base Rate [Member] | Revolving Credit Agreement 2020 [Member]
Line of Credit Facility [Line Items]
Weighted average interest rate (in hundredths)	5.00%

v3.10.0.1

Fair Value Measurements (Details) - USD ($) $ in Millions	6 Months Ended
	Jun. 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	$ 163
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	32
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	6,419	6,602
Commodity Contract [Member] | Crude Oil [Member] | Price Swaps [Member]
Financial Liabilities:
Financial and Nonfinancial Liabilities, Fair Value Disclosure	261	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	261	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	83
Financial Liabilities:
Financial and Nonfinancial Liabilities, Fair Value Disclosure		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	83
Financial Liabilities:
Financial and Nonfinancial Liabilities, Fair Value Disclosure		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
Commodity Contract [Member] | Natural Gas [Member] | Price Swaps [Member]
Financial Assets: [Abstract]
Assets, Fair Value Disclosure	0	2
Commodity Contract [Member] | Natural Gas [Member] | Price Swaps [Member] | Fair Value, Inputs, Level 1 [Member]
Financial Assets: [Abstract]
Assets, Fair Value Disclosure	0	0
Commodity Contract [Member] | Natural Gas [Member] | Price Swaps [Member] | Fair Value, Inputs, Level 2 [Member]
Financial Assets: [Abstract]
Assets, Fair Value Disclosure	0	2
Commodity Contract [Member] | Natural Gas [Member] | Price Swaps [Member] | Fair Value, Inputs, Level 3 [Member]
Financial Assets: [Abstract]
Assets, Fair Value Disclosure	0	0
Commodity Contract [Member] | Natural Gas [Member] | Commodity Option [Member]
Financial Assets: [Abstract]
Assets, Fair Value Disclosure	2
Commodity Contract [Member] | Natural Gas [Member] | Commodity Option [Member] | Fair Value, Inputs, Level 1 [Member]
Financial Assets: [Abstract]
Assets, Fair Value Disclosure	0
Commodity Contract [Member] | Natural Gas [Member] | Commodity Option [Member] | Fair Value, Inputs, Level 2 [Member]
Financial Assets: [Abstract]
Assets, Fair Value Disclosure	2
Commodity Contract [Member] | Natural Gas [Member] | Commodity Option [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)		6 Months Ended
		Jun. 30, 2018 USD ($) MMBTU $ / bbl $ / MMBTU bbl	Dec. 31, 2017 USD ($)
Derivatives, Fair Value [Line Items]
Assets from Price Risk Management Activities		$ 1,840,000	$ 7,699,000
Liabilities from Price Risk Management Activities		195,457,000	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		17,000,000	0
Liabilities From Price Risk Management Activities [Member]
Derivatives, Fair Value [Line Items]
Assets from Price Risk Management Activities		66,000,000	5,000,000
Liabilities from Price Risk Management Activities		261,000,000	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]	195,000,000	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 July (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 - August 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 - January through July (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 - August through December [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 Year Two - January through December [Member]
Derivatives, Fair Value [Line Items]
Volume (Bbld) | bbl		8,000
Derivative, Swap Type, Average Fixed Price | $ / bbl		5.660
Crude Oil [Member] | Price Swaps [Member] | Derivative Contracts - January through June (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 - July 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 July (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 - August through 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 July (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 - August through 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 July (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 - August through 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 $261 million, partially offset by gross assets of $66 million at June 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	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Discontinued Operations and Disposal Groups [Abstract]
Losses on Asset Dispositions, Net	$ (6,317)	$ (8,916)	$ (21,286)	$ (25,674)
Proceeds from Sale of Oil and Gas Property and Equipment			$ 8,276	$ 175,260

This regulatory filing also includes additional resources:
eog2018063010q.pdf