EXHIBIT 99.1

·	Delivers 39 Percent Year-Over-Year Total Company Crude Oil Production Growth

·	Raises 2013 Full-Year Crude Oil Production Goal to 39 Percent from 35 Percent

·	Increases 2013 Total Company Production Growth Target to 9 Percent from 7.5 Percent

·	Reports Record Western Eagle Ford Oil Well

·	Continues to Achieve Stellar Economic Results from the Eagle Ford, Bakken/Three Forks and Leonard Plays

·	Announces Mark G. Papa Will Continue as Director Following Year-end Retirement

FOR IMMEDIATE RELEASE: Wednesday, November 6, 2013

HOUSTON – EOG Resources, Inc. (EOG) today reported third quarter 2013 net income of $462.5 million, or $1.69 per share. This compares to third quarter 2012 net income of $355.5 million, or $1.31 per share.

Consistent with some analysts' practice of matching realizations to settlement months and making certain other adjustments in order to exclude one-time items, adjusted non-GAAP net income for the third quarter 2013 was $634.3 million, or $2.32 per share. Adjusted non-GAAP net income for the third quarter 2012 was $468.7 million, or $1.73 per share. The results for the third quarter 2013 included net gains on asset dispositions of $5.2 million, net of tax ($0.02 per share), impairments of $2.4 million, net of tax ($0.01 per share) related to the sale of certain non-core North American assets and a previously disclosed non-cash net loss of $293.4 million ($187.8 million after tax, or $0.69 per share) on the mark-to-market of financial commodity contracts. During the third quarter, the net cash outflow related to financial commodity contracts was $20.6 million ($13.2 million after tax, or $0.05 per share). (Please refer to the attached tables for the reconciliation of adjusted non-GAAP net income to GAAP net income.)

EOG reported strong, sustained financial growth for the first nine months of 2013. Earnings per share increased 49 percent, discretionary cash flow increased 29 percent and adjusted EBITDAX rose 27 percent, compared to the same 2012 period. (Please refer to the attached tables for the reconciliation of non-GAAP discretionary cash flow to net cash provided by operating activities (GAAP) and adjusted EBITDAX (non-GAAP) to income before interest expense and income taxes (GAAP).)

EOG increased its U.S. crude oil and condensate production by 41 percent and total company crude oil and condensate production by 39 percent in the third quarter of 2013 over the same prior year period. Total company liquids production – crude oil, condensate and natural gas liquids (NGLs) – rose 33 percent.

EOG is increasing its full year crude oil and condensate production growth target for the second time in 2013 to 39 percent from 35 percent, following three quarters of extraordinary results. Total natural gas liquids production is expected to increase 17 percent, compared to the previous 14 percent target, and total natural gas production is projected to decline 11 percent, consistent with EOG's longstanding strategy in North America. Overall, EOG is targeting 9 percent total company production growth in 2013, versus its previous goal of 7.5 percent. In addition, EOG is again lowering certain unit cost estimates, based on results to date.

"EOG is consistently making the best oil wells in the best two oil plays in North America, the Eagle Ford and Bakken/Three Forks," said President and Chief Executive Officer William R. "Bill" Thomas.

In the first three quarters of 2013, EOG built momentum in its western Eagle Ford acreage by increasing drilling activity from six to nine rigs. Through completion advancements, initial production rates have increased more than 20 percent since the first quarter 2013. This enhanced productivity across Atascosa, La Salle and McMullen Counties mirrors the performance level EOG already has reached in its eastern play activities.

During the third quarter, EOG reported its top well to date from its western Eagle Ford acreage. The Kaiser Junior Unit #1H began initial production at 2,815 barrels of oil per day (Bopd) with 160 barrels per day (Bpd) of NGLs and 940 thousand cubic feet per day (Mcfd) of natural gas in Atascosa County. Other third quarter western wells include the Janet Unit #1H and Nelson Zella Unit #1H and #2H in La Salle County, which were completed with initial rates of 2,430, 1,960 and 2,810 Bopd with 175, 120 and 100 Bpd of NGLs and 1,000, 700 and 590 Mcfd of natural gas, respectively. In McMullen County, the River Lowe Ranch #4H, #5H, #6H, #7H, #8H and #9H began sales at initial rates ranging from 1,970 to 2,115 Bopd with 125 to 135 Bpd of NGLs and 720 to 780 Mcfd of natural gas. EOG has 100 percent working interest in these 10 wells.

Highlights from EOG's eastern Eagle Ford acreage include four DeWitt County wells. The Justiss Unit #1H, #2H and #3H were completed at 3,885, 3,560 and 3,940 Bopd with 520, 605 and 670 Bpd of NGLs and 3.0, 3.5 and 3.9 million cubic feet per day (MMcfd) of natural gas, respectively. Also in DeWitt County, the Vinklarek Unit #1H was completed at 4,510 Bopd with 715 Bpd of NGLs and 4.2 MMcfd of natural gas. In Gonzales County, the Baker-Deforest Unit #5H, #6H and #7H came on-line at 3,200, 3,560 and 4,115 Bopd with 420, 490 and 535 Bpd of NGLs and 2.5, 2.9 and 3.1 MMcfd of natural gas, respectively. EOG has 100 percent working interest in these seven Eagle Ford wells.

"Because we now are achieving high growth, high rate-of-return results from our western acreage, we have effectively raised the bar for all of EOG's Eagle Ford acreage," Thomas said.

With a 25-rig drilling program, EOG is increasing the total net wells planned across its Eagle Ford acreage in 2013 from 440 to 460.

EOG's exceptional Eagle Ford results were replicated in the North Dakota Bakken/Three Forks through improvements in initial production rates and efficient execution of its drilling program.

In the Bakken Core, EOG brought a number of Mountrail County wells to sales. The Fertile 50-0509H, in which EOG has 100 percent working interest, began producing crude oil at 2,315 Bopd with 1.0 MMcfd of rich natural gas. The Van Hook 126-2523H and 130-2526H came on-line at peak rates of 2,235 and 1,910 Bopd with 1.1 and 0.9 MMcfd of rich natural gas, respectively. EOG has 67 and 91 percent working interest in these wells, respectively. The Wayzetta 155-2636H, 137-2226H and 150-1509H had initial crude oil rates ranging from 2,060 to 2,500 Bpd with 1.0 to 1.2 MMcfd of rich natural gas. EOG has 72 percent, 65 percent and 63 percent working interest in these wells, respectively.

On its Antelope Extension acreage in McKenzie County, EOG highlighted three wells from the first bench of the Three Forks formation. The Bear Den 100-2017H and 101-2019H began producing at rates of 2,100 and 1,235 Bopd with 2.0 and 1.2 MMcfd of rich natural gas, respectively. The third well, the Bear Den 23-2019H had an initial production rate of 1,665 Bopd with 1.6 MMcfd of rich natural gas. EOG has 91 percent working interest in these three wells.

EOG remains focused on the highly economic Bakken Core and Antelope Extension areas. Based on continuous gains in results from both the Bakken and Three Forks formations, plans are to increase the level of drilling activity in 2014.

"Every quarter, EOG's technical understanding of the Eagle Ford and Bakken/Three Forks expands, as we further modify completion techniques that boost overall well productivity and economics," Thomas said.

During the third quarter, EOG completed three wells in the Delaware Basin Leonard play in Lea County, New Mexico. The Endurance 36 State Com #3H and #4H and Brown Bear 36 State #1H began production at 735, 875 and 720 Bopd, respectively. The wells, in which EOG has 100 percent working interest, also produced 85, 105 and 120 Bpd of NGLs with 460, 570 and 665 Mcfd of natural gas, respectively. Plans are to increase drilling activity in the Leonard in 2014.

"With premier positions in the Eagle Ford and Bakken/Three Forks, EOG continues to set new crude oil production records. Through our tenacious attention to the completion process, we are enhancing the productivity and profitability of these world class assets to ultimately realize a greater volume of the potential oil in the ground," said Mark G. Papa, Executive Chairman of the Board. "We also are pleased with the strides EOG is making in the Delaware Basin Leonard."

In recent weeks, EOG increased the amount of crude oil hedges in place for the remainder of 2013 and 2014. For the period November 1 through December 31, 2013, EOG has crude oil financial price swap contracts in place for 126,000 Bopd at a weighted average price of $98.80 per barrel, excluding unexercised options.

For the period January 1 through June 30, 2014, EOG has crude oil financial price swap contracts in place for approximately 123,000 Bopd at a weighted average price of $96.44 per barrel, excluding unexercised options. For the period July 1 through December 31, 2014, EOG has crude oil financial price swap contracts in place for 9,000 Bopd at an average price of $95.30 per barrel, excluding unexercised options.

EOG also has hedges in place for natural gas volumes. For December 2013, EOG has natural gas financial price swap contracts in place for 150,000 million British thermal units per day (MMBtud) at a weighted average price of $4.79 per million British thermal units (MMBtu), excluding unexercised options. For the full year 2014, EOG has natural gas financial price swap contracts in place for 170,000 MMBtud at a weighted average price of $4.54 per MMBtu, excluding unexercised options. (For a comprehensive summary of crude oil and natural gas derivative contracts, please refer to the attached tables.)

For the first nine months of 2013, EOG's cash flows from operating activities and proceeds from asset sales exceeded total capital expenditures.

To date, EOG has closed on approximately $620 million of asset sales, exceeding its stated goal for the year. Proceeds from asset sales for the full year 2013 are expected to be approximately $750 million. At September 30, 2013, EOG's total debt outstanding was $6,313 million for a debt-to-total capitalization ratio of 30 percent. Taking into account cash on the balance sheet of $1,319 million at the end of the third quarter, EOG's net debt was $4,994 million for a net debt-to-total capitalization ratio of 25 percent. (Please refer to the attached tables for the reconciliation of net debt (non-GAAP) to current and long-term debt (GAAP) and the reconciliation of net debt-to-total capitalization ratio (non-GAAP) to debt-to-total capitalization ratio (GAAP).)

As previously announced, in addition to his current role as Chief Executive Officer, Thomas will succeed Papa as Chairman of the Board on January 1, 2014. Papa will retire both as Executive Chairman of the Board and as an employee at year-end, although he will continue to serve as an EOG director.

EOG's third quarter 2013 results conference call will be available via live audio webcast at 8 a.m. Central time (9 a.m. Eastern time) on Thursday, November 7, 2013. To listen, log on to www.eogresources.com. The webcast will be archived on EOG's website through November 21, 2013.

EOG Resources, Inc. is one of the largest independent (non-integrated) crude oil and natural gas companies in the United States with proved reserves in the United States, Canada, Trinidad, the United Kingdom and China. EOG Resources, Inc. is listed on the New York Stock Exchange and is traded under the ticker symbol "EOG."

This press release includes forward-looking statements within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended.  All statements, other than statements of historical facts, including, among others, statements and projections regarding EOG's future financial position, operations, performance, business strategy, returns, budgets, reserves, levels of production and costs, statements regarding future commodity prices and statements regarding the plans and objectives of EOG's management for future operations, are forward-looking statements.  EOG typically uses words such as "expect," "anticipate," "estimate," "project," "strategy," "intend," "plan," "target," "goal," "may," "will," "should" and "believe" or the negative of those terms or other variations or comparable terminology to identify its forward-looking statements.  In particular, statements, express or implied, concerning EOG's future operating results and returns or EOG's ability to replace or increase reserves, increase production, generate income or cash flows or pay dividends are forward-looking statements.  Forward-looking statements are not guarantees of performance.  Although EOG believes the expectations reflected in its forward-looking statements are reasonable and are based on reasonable assumptions, no assurance can be given that these assumptions are accurate or that any of these expectations will be achieved (in full or at all) or will prove to have been correct.  Moreover, EOG's forward-looking statements may be affected by known, unknown or currently unforeseen risks, events or circumstances that may be outside EOG's control.  Important factors that could cause EOG's actual results to differ materially from the expectations reflected in EOG's forward-looking statements include, among others:

·	the timing and extent of changes in prices for, 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 can optimize reserve recovery and economically develop its plays utilizing horizontal and vertical drilling, advanced completion technologies and hydraulic fracturing;

·

the extent to which EOG is successful in its efforts to economically develop its acreage in, and to produce reserves and achieve anticipated production levels from, its existing and future crude oil and natural gas exploration and development projects, given the risks and uncertainties and capital expenditure requirements inherent in drilling, completing and operating crude oil and natural gas wells and the potential for interruptions of development and production, whether involuntary or intentional as a result of market or other conditions;

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

·	the availability, proximity and capacity of, and costs associated with, gathering, processing, compression and transportation 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 laws and regulations relating to air emissions, waste disposal, hydraulic fracturing and access to and use of water, laws and regulations imposing conditions and restrictions on drilling and completion operations and laws and regulations with respect to derivatives and hedging activities;

·	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 employees and other personnel, equipment, materials and services and, related thereto, the availability and cost of employees and other personnel, equipment, materials 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 of production, gathering, processing, 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 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;

·	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 16 through 23 of EOG's Annual Report on Form 10-K for the fiscal year ended December 31, 2012 and any updates to those factors set forth in EOG's subsequent Quarterly Reports on Form 10-Q or Current Reports on Form 8-K.

In light of these risks, uncertainties and assumptions, the events anticipated by EOG's forward-looking statements may not occur, and, if any of such events do, we may not have anticipated the timing of their occurrence or the extent of their impact on our actual results.  Accordingly, you should not place any undue reliance on any of EOG's forward-looking statements. EOG's forward-looking statements speak only as of the date made, and EOG undertakes no obligation, other than as required by applicable law, to update or revise its forward-looking statements, whether as a result of new information, subsequent events, anticipated or unanticipated circumstances or otherwise.

The United States Securities and Exchange Commission (SEC) permits oil and gas companies, in their filings with the SEC, to disclose not only "proved" reserves (i.e., quantities of oil and gas that are estimated to be recoverable with a high degree of confidence), but also "probable" reserves (i.e., quantities of oil and gas that are as likely as not to be recovered) as well as "possible" reserves (i.e., additional quantities of oil and gas that might be recovered, but with a lower probability than probable reserves).  As noted above, statements of reserves are only estimates and may not correspond to the ultimate quantities of oil and gas recovered. Any reserve estimates provided in this press release that are not specifically designated as being estimates of proved reserves may include "potential" reserves and/or other estimated reserves not necessarily calculated in accordance with, or contemplated by, the SEC's latest reserve reporting guidelines.  Investors are urged to consider closely the disclosure in EOG's Annual Report on Form 10-K for the fiscal year ended December 31, 2012, available from EOG at P.O. Box 4362, Houston, Texas 77210-4362 (Attn: Investor Relations). You can also obtain this report from the SEC by calling 1-800-SEC-0330 or from the SEC's website at www.sec.gov.  In addition, reconciliation and calculation schedules for non-GAAP financial measures can be found on the EOG website at www.eogresources.com.