NYSE Stock Symbol: EOGCommon Dividend: $0.75Basic Shares Outstanding: 271.7 Million

Internet Address:http://www.eogresources.com

Investor Relations ContactsMaire A. Baldwin, Vice President IR

(713) 651-6364, Fax (713) 651-6473mbaldwin@eogresources.com

Elizabeth M. Ivers, Director IR(713) 651-7132, eivers@eogresources.com

Kimberly A. Matthews, Manager IR(713) 571-4676, kmatthews@eogresources.com

Copyright; Assumption of Risk: Copyright 2013. This presentation and the contents of this presentation have been copyrighted by EOG Resources, Inc. (EOG). All rights reserved. Copying of the presentation is forbidden without the prior written consent of EOG. Information in this presentation is provided "as is" without warranty of any kind, either express or implied, including but not limited to the implied warranties of merchantability, fitness for a particular purpose and the timeliness of the information. You assume all risk in using the information. In no event shall EOG or its representatives be liable for any special, indirect or consequential damages resulting from the use of the information.

Cautionary Notice Regarding Forward-Looking Statements: This presentation 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 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" 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 and unknown 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;• 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 developments around the world, including in the areas in which EOG operates;• the use of competing energy sources and the development of alternative energy sources;• the extent to which EOG incurs uninsured losses and liabilities or losses and liabilities in excess of its insurance coverage;• acts of war and terrorism and responses to these acts; and• the other factors described under Item 1A, "Risk Factors", on pages 15 through 23 of EOG's Annual Report on Form 10-K for the fiscal year ended December 31, 2011 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.

Oil and Gas Reserves; Non-GAAP Financial Measures: Effective January 1, 2010, 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 presentation 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, 2011, 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.

EOG_0213-1

Operations

Eagle Ford - Increased Estimated Potential Reserves* by 38%

• 1.6 BnBoe to 2.2 BnBoe, Net to EOGDelaware Basin- Increased Leonard Shale Estimated Potential Reserves*

• From 65 to 550 MMBoe, Net to EOG - 50% Crude Oil- Added New Wolfcamp Shale Estimated Potential Reserves*

• 800 MMBoe, Net to EOG - Combo Play - 31% Crude, 33% NGL, 36% Gas- Combined Delaware Basin Estimated Potential Reserves* 1.35 BnBoe, Net to EOG

39% YOY Crude Oil GrowthStrong Profit and Cash Flow Growth vs 2011- Adjusted Non-GAAP EPS 50%; Adjusted EBITDAX 26%; Discretionary Cash Flow 26%

Total Company Crude Oil YOY Target of 28%* Estimated potential reserves, not proved reserves.** See reconciliation schedules.*** Based on mid-point of full-year 2013 production estimates as of February 13, 2013.

2012 Financials**

2013E Production Growth***

EOG_0213-2

All About Oil

Grow Crude Oil 28% YOY*

Focus on Eagle Ford, Bakken and Permian

Improve Recovery Factors in Existing Plays

Focus on New Greenfield Oil or Combo Plays

Negligible North American Dry Gas Investments

Maintain Net Debt-to-Total Cap Ratio <30%

* Based on mid-point of full-year 2013 estimates as of February 13, 2013.

EOG_0213-3

Strong Liquids Growth Driven by Crude Oil, Not Condensate or NGLs

Premium Net Backs- Crude-by-Rail – EOG-Owned Infrastructure in Place at Cushing and St. James

• Maximizing Delivery Capability at St. James (LLS)• Majority of U.S. Oil Prices based on LLS

Costs- Sand from EOG-Owned Mines Reduces Completion Costs- High Growth Rates Reducing Per Unit Operating Costs

Best Hz Crude Oil Assets in North America

Strong Organic Crude Oil Production Growth- 2010 +35%- 2011 +52%- 2012 +39%- 2013E* +28%

Differentiators

* Based on the mid-point of full-year 2013 production estimates as of February 13, 2013.

39% Average

EOG_0213-4

EOG Loading FacilityEOG Unloading FacilityPrompt Month Pricing at February 11, 2013Rail

Stanley, ND

Cushing, OK

St. James, LA

Clearbrook, MN

WTI$97

LLS$117

$93

Permian

Eagle Ford

Innovator for Crude-by-Rail - ≈ 4 Years Experience- Competitive with Existing and Announced

Pipe Expansions- Access to Premium Markets- Provides Market Flexibility

EOG-Owned Infrastructure

Loading Facilities- Bakken- Permian- Eagle Ford

Unloading Facilities- Cushing, OK (WTI)- St. James, LA (LLS/Brent)

Currently Priced Off LLS Index

EOG_0213-5

9.4%10.3%

2012* 2013E**

11.8%13.1%

2012* 2013E**

* See reconciliation schedules.** Goldman Sachs estimates February 1, 2013, $97 WTI and $3.75 Henry Hub in 2013.

ROE ROCE

EOG_0213-6

0

200,000

400,000

600,000

800,000

1,000,000

1,200,000

1,400,000

1,600,000

Jan2005

Jul2005

Jan2006

Jul2006

Jan2007

Jul2007

Jan2008

Jul2008

Jan2009

Jul2009

Jan2010

Jul2010

Jan2011

Jul2011

Jan2012

Jul2012

Woodford Mississippian Niobrara Barnett MidContinent Permian Bakken Eagle Ford

* Source: IHS Data through September 2012. OK production after July 2012 is not fully reported.Select Onshore Lower 48 formations with growing crude oil production.

Eagle Ford

Bakken

559 Mbod*

688 Mbod*

Bakken and Eagle Ford ≈ 82% of Current Horizontal Crude Oil Production*

1,200

1,000

800

600

400

200

0

1,400

1,600

MB

od

EOG_0213-7

* Source: IHS – Data as of Sep 2012. Select onshore Lower 48 formations with growing crude oil production. OK production after July 2012 is not fully reported.Peers include: APC, CHK, CLR, COP, HES, MRO, STO, WLL and XOM.

0

25

50

75

100

125

150

175

200

EOG Co. 1 Co. 2 Co. 3 Co. 4 Co. 5 Co. 6 Co. 7 Co. 8 Co. 9

EOG is Industry Leader by >2:1 Ratio

EOG_0213-8

0

2,000

4,000

6,000

8,000

10,000

12,000

14,000

16,000

Jan-

1920

Jan-

1924

Jan-

1928

Jan-

1932

Jan-

1936

Jan-

1940

Jan-

1944

Jan-

1948

Jan-

1952

Jan-

1956

Jan-

1960

Jan-

1964

Jan-

1968

Jan-

1972

Jan-

1976

Jan-

1980

Jan-

1984

Jan-

1988

Jan-

1992

Jan-

1996

Jan-

2000

Jan-

2004

Jan-

2008

Jan-

2012

Imports

Production

10

8

6

4

2

0

12

16

14

* Source: EIA / Data through Nov 2012

EOG_0213-9

Improve Recovery Factor of Oil-in-Place in Existing Plays- Testing

• Denser Well Spacing• Secondary Recovery Methods

Continue to Explore for New Hz Oil/Liquids Prospects Onshore North America- Leverage Expertise in Hz Shales

EOG Has Best Onshore U.S. Oil Assets- Find Ways to Make Them Better

EOG_0213-10

* Based on mid-point of full-year 2013 production estimates as of February 13, 2013.

Crude and Condensate(Mbd)

Total Liquids(Mbd)

4362

79105

156

214

263

2007 2008 2009 2010 2011 2012 2013E*

~~

3146 55

75

113

158

202

2007 2008 2009 2010 2011 2012 2013E*

~~

EOG_0213-11

Eagle Ford

Bakken/Three Forks

Delaware Basin- Leonard- Wolfcamp

Midland Basin Wolfcamp

Barnett

* Based on current technology. Assumes no further downspacing.

2013 Drilling Wells (Net) Years*

≈ 15 Years of Drilling

400

53

16 10

35

130

Combo

12

7

83 118

29

9

Oil

EOG_0213-12

* Based on full-year estimates as of February 13, 2013.

Exploration and Development

83%

Exploration and Development Facilities

10%

Gathering,Processing and Other

7%

2013E Capex ≈ $7.0 to $7.2 Bn* Including Facilities and Midstream

Continued Strong Best-in-Class Double-Digit Liquids GrowthEagle Ford and Bakken Oil are Primary Capex Focus Negligible North American Dry Gas Drilling ≈ $25 MMAt Current Oil Prices – Negligible Funding Gap- $550 MM Asset Sales Anticipated ≈ 85% Already Closed Through February 12Maintain <30% Net Debt-to-Total Cap Ratio at YE 2013

2013E Outlook

EOG_0213-13

2013E*

Crude Oil and Condensate

NGLs

Total Company Liquids

North American Gas**

Other Gas***

Total Company

Total North America

2010

35%

29%

33%

-2%

24%

9.5%

7%

* Based on the mid-point of full-year 2013 production estimates as of February 13, 2013. Liquids converted at 6:1 ratio. Net of planned dispositions/sales.** 2013 North American gas estimates net of planned dispositions/sales.*** Contingent on Trinidad market conditions.

52%

39%

48%

-7%

--%

9.4%

12%

28%

10%

23%

-15%

-4%

4%

4%

2014+

ContinuedBest-in-ClassDouble-Digit

Growth

2011

Highest Annual Organic Crude Oil Growth of Large Cap E&P Peer Group Over Last Four Years

Tolerance +/-2%

Negative

Flat

39%

32%

37%

-9%

9%

10.3%

11%

2012

EOG_0213-14

21%24%

29%

41%

53%

72%

86% 88%

79%76%

71%

59%

47%

28%

14% 12%

2006 2007 2008 2009 2010 2011 2012 2013E**

Liquids (Crude Oil and NGLs) Natural Gas

* 2006 - 2012 based on North American actual revenues. FY 2013E based on NYMEX 2013 Current/Forward Oil to Gas Prices converted as follows: Oil at 33:1 and NGLs at 12:1. ** Based on the mid-point of full-year 2013 production estimates as of February 13, 2013.

Oil

NGLs

≈

≈

EOG_0213-15

$23.86$20.04

$29.29

$34.11

$0.00

$5.00

$10.00

$15.00

$20.00

$25.00

$30.00

$35.00

$40.00

2009 2010 2011 2012

32%

41%

56%

71%

0%

20%

40%

60%

80%

% Crude OilRevenues

* Wellhead Revenues for Crude Oil and Condensate, Natural Gas Liquids and Natural Gas less Lease and Well, Transportation Costs, Exploration Costs, Dry Hole Costs, Generaland Administrative, Taxes Other than Income and Net Interest Expense plus any Realized Gains (Losses) on Commodity Derivative Contracts, calculated on a per unit basis.

EOG_0213-16

-40%

-30%

-20%

-10%

0%

10%

20%

30%

40%

50%

60%

70%

80%

90%

Source: Goldman Sachs estimates February 1, 2013, $97 WTI and $3.75 Henry Hub in 2013.* Peers Include: APA, APC, CHK, COG, DVN, ECA, NFX, NBL, PXD, RRC, SWN and UPL.

EOG Co. 1 Co. 2 Co. 3 Co. 4 Co. 6Co. 5 Co. 7

Co. 8 Co. 9 Co. 10 Co. 11 Co. 12

EOG +83%Peer Avg +3%

PeerAvg

EOG_0213-17

Source: Goldman Sachs estimates February 1, 2013, $97 WTI and $3.75 Henry Hub in 2013.* Peers Include: APA, APC, CHK, COG, DVN, ECA, NFX, NBL, PXD, RRC, SWN and UPL.

-20%

-10%

0%

10%

20%

30%

EOG +29%Peer Avg +6%

EOG Co. 1 Co. 2 Co. 3 Co. 4 Co. 6Co. 5 PeerAvg

Co. 8

Co. 9 Co. 10

Co. 7

Co. 11 Co. 12

EOG_0213-18

* Adjusted for 2-for-1 Stock Split Effective March 1, 2005.** Indicated current level, effective April 2013.

$0.06 $0.07 $0.08 $0.08 $0.10$0.12

$0.16

$0.24

$0.36

$0.51

$0.58$0.61

$0.64$0.67

$0.75

$0.00

$0.10

$0.20

$0.30

$0.40

$0.50

$0.60

$0.70

1999* 2000* 2001* 2002* 2003* 2004* 2005 2006 2007 2008 2009 2010 2011 2012 2013E**

14 Dividend Increases in 14 Years

EOG_0213-19

* Tables with Supporting Data and Reconciliation Schedules posted to EOG website, www.eogresources.com.

Increased Total Company Net Proved Liquids Reserves 37% to 1,021 MMBbls- Liquid Reserves Increased to 56% of Total Reserves

Total Company Liquids Reserve Replacement* 452%- Total Company Reserve Replacement* 268%, Excluding Price-Related Revisions- Liquids Compose 80% of Reserve Adds in North America and U.S.

Very Attractive Reserve Replacement Costs* ($/Boe)- All-in, Excluding Price-Related Revisions $12.60- U.S. All-in, Excluding Price-Related Revisions $11.82- Total Company Drilling, Before Revisions $17.01

EOG_0213-20

WindowCrude OilWet GasDry GasTotal

EOG Has Captured the Biggest U.S. Crude Oil Discovery Net to One Company in the Past ≈ 40 Years

Increased Estimated Potential Reserves* by 38% Oil MMBo 1,500NGLs MMBbl 375Gas Bcf 1,950Total MMBoe, Net to EOG 2,200

Largest Oil Producer in the Eagle Ford≈ 106 MBoepd, Net at December 31, 2012- Total 2012 Average 94.4 MBoepd, Net

Continued Outstanding Well Results- Record Well - Burrow Unit #2H – IP >6,300 Bopd

Net Acres569,00021,00049,000

639,000

Oil 78%

Gas 12%

NGLs10%

Current Production Mix

* Estimated potential reserves, not proved reserves. Includes 552 MMBoe proved reserves booked at December 31, 2012.

Crude OilWindow

Dry GasWindow

Wet GasWindow

0 25 Miles

San Antonio

Laredo

Corpus Christi

EOG 639,000 Net Acres

EOG_0213-21

Second Round of Reserve Increase

1.6 BnBoe to 2.2 BnBoe Potential*, Net to EOG

Estimated 8% Recovery of Estimated 26.4 BnBoe in Place, Net to EOG

4,900 Drilling Locations Yet to Complete- 40-Acre Spacing in East- 65-Acre Spacing in West

Estimated 400 MBoe Reserves Per Well, NAR

2013 Operations

Current Well Economics – 100% Direct ATROR**

Plan to Drill ≈ 400 Net Wells with ≈ 26 Rigs

Continue to Decrease Number of Drilling Days, Currently ≈ 13

Using EOG Self-Sourced Sand to Decrease Well Costs and Increase Efficiencies

$6 MM CWC Target for 5,500’ Average Lateral Length Well * Estimated potential, not proved reserves.** See reconciliation schedule.

EOG_0213-22

Cum

ulat

ive

Oil

Prod

uctio

n* (M

MB

O)

Weighted Average Oil Gravity (°API)

Label: Cumulative Oil Production (MMBO), Current Rate (MBOD)* Source IHS; Production as of October 2012: Operators with > 5MMBo Cumulative Oil ProductionPeers Include: APC, CHK, COP, GeoSouthern, MRO, MUR, PXD, PXP, ROSE

Co. 527 MMBO, 64 MBOD

Co. 724 MMBO, 42 MBOD

Co. 96 MMBO, 11 MBOD

Co. 619 MMBO, 31 MBOD

Co. 121 MMBO, 74 MBOD

Co. 49 MMBO, 31 MBODCo. 2

7 MMBO, 21 MBOD

EOG46 MMBO, 97 MBOD

Co. 818 MMBO, 41 MBODCo. 3

16 MMBO, 44 MBOD

Oil Condensate

EOG_0213-23

0 25 Miles

EOG 569,000 Net Acres in Crude Oil Window

Boysen Unit #1H andBaird Heirs Unit #4H

IPs: 2,540 and 2,242 Bopd + 268 and 181 Bpd of NGLs + 1.6 and 1.1 MMcfd

Henkhaus Unit #8HIP: 4,012 Bopd + 495 Bpd of NGLs + 3.0 MMcfd

Lowe Pasture #9H and #10H IPs: 1,905 and 2,075 Bopd + 112 and 115 Bpd of NGLs + 673 and 688 Mcfd

Reilly Unit #1HIP: 3,579 Bopd + 483 Bpd of NGLs + 2.9 MMcfd

Baker-DeForest Unit #4HIP: 4,598 Bopd with 488 Bpd of NGLs+ 2.9 MMcfd

Baker-DeForest Unit #1H, #2H, #3H and #12HIP Range: 3,346 to 4,216 Bopd + 457 to

537 Bpd of NGLs + 2.7 to 3.2 MMcfd

Boothe Unit #1H and #2HIP: 5,380 and 3,810 Bopd

+ 625 and 525 Bpd of NGLs + 3.6 and 3.0 MMcfd

Burrow Unit #1H and #2HIP: 5,424 and 6,331 Bopd + 600 and 713 Bpd of

NGLs + 3.5 and 4.1 MMcfdSan Antonio

Martindale L&C #1H and #2H IPs: 1,522 and 1,876 Bopd + 220 and

208 Bpd of NGLs + 1.3 and 1.2 MMcfdNaylor Jones Unit 59 East #1H and West #4H IPs: 1,670 and 1,150 Bopd + 225 and 138 Bpd

of NGLs + 1.3 and 0.8 MMcfd

EOG_0213-24

17

19

16

1314

11

8 8 9

Karnes Trough Gonzales Trough West Monocline

2011 2012 Record

EOG_0213-25

Gas 2%

NGLs6%

Core Well

Oil92%

Oil87%

Canada

20 Miles

Bakken Subcrop

EOG Acreage – Bakken/Three ForksBakken Oil Saturated

Core Area

Wayzetta Wells

One of Top Oil Producers in North Dakota- 62.1 MBoed Gross Production at YE 2012Improved Well Results in All Areas with New Frac Techniques

Note: 167 MMBoe proved reserves in Bakken/Three Forks booked at December 31, 2012.

Core Area

Antelope Extension

WaterInjection

Pilots

Stanley, ND

Antelope WellNGLs11%

Gas 11%

Success with 320-Acre DownspacingEncouraging Early Results with 160-Acre Downspacing- 2 Wayzetta Wells – IPs 1,185 and 1,265 Bopd + Rich Gas

Antelope Extension

Both Bakken and Three Forks PotentialContinued Success with 320-Acre Spacing - Hawkeye Wells – IP 2,945 and 2,445 Bopd + Rich Gas- Testing 160 Acres- -Operations

Plan to Complete 53 Net Wells in 2013- Majority in Prolific Core and Antelope AreasInnovative Crude-by-Rail System- Securing LLS Pricing at St. JamesUsing EOG Self-Sourced Sand Oil

78%

EOG_0213-26

115

197

2012E 2013E

* Production normalized to lateral length

OriginalOffset Wells

Wayzetta 156-3329H Infill Well

47

60

2012E 2013EOriginalOffset Wells

Fertile 46-1608HInfill Well

* 300-Day Results * 170-Day Results

EOG_0213-27

0

100

200

300

400

500

600

EOG RESOURCES,INC.

HELIS OIL & GASCOMPANY LLC

WHITINGPETROLEUM

MUREXPETROLEUM

CORPORATION

DAKOTA-3 E&PCOMPANY, LLC

SLAWSONEXPLORATION

COMPANYINCORPOR

QEP ENERGYCOMPANY

HUNT OIL COMPANY FIDELITYEXPLORATION &PRODUCTION CO

ENERPLUSRESOURCES (USA)

CORPORATION

BRIGHAM OIL & GASL P

KODIAK OIL & GASUSA

INCORPORATED

ZENERGYOPERATING CO,

LLC

DENBURYONSHORE, LLC

PETRO-HUNT LLC OXY USA INC HESSCORPORATION

OASIS PETROLEUMNORTH AMERICA

LLC

NORTH PLAINSENERGY LLC

CONTINENTALRESOURCES, INC.

MARATHON OILCOMPANY

NEWFIELDPRODUCTION

COMPANY

SINCLAIR OIL & GASCOMPANY

CONOCOPHILLIPS SM ENERGYCOMPANY

XTO ENERGYINCORPORATED

ENCOREOPERATING

LIMITEDPARTNERSHIP

TRACKERRESOURCES

DEVELOPMENT IILLC

BAYTEX ENERGYUSA LIMITED

SAMSONRESOURCES

COMPANY

CORNERSTONENATURAL

RESOURCES LLC

J P OIL COMPANYINCORPORATED

BTA OILPRODUCERS LLCEOG 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32

Total 3,814 WellsEOG Average EUR 544 MBoField Average EUR 338 MBo

Source: IHS, May 2012Other Operators: BTE, CLR, COP, ERF, HES, KOG, MRO, NBL, NFX, OAS, OXY, QEP, SM, SMM, SSN, STO, WLL, WPX, XOM and private companies.

Field Average

EOG_0213-28

Estimated Reserve Potential* ≈ 800 MMBoe, Net to EOG- Multiple Target Zones, 50 to 300 MMBoe/Section,

Resource in Place- Based on Recent Wells and >200 Previously Drilled

Vertical Wells on EOG Acreage

114,000 Net Acres – 10 Net Wells Planned in 2013

Estimated Reserves/Well 900 Mboe, Gross; 700 Mboe, NAR

Target CWC $6.5MM and 60% Direct ATROR**

Recent Well Results – Reeves, County, TXBopd + NGLs Bpd + MMcfd

Harrison Ranch 56 #1001H 635 480 3.1Harrison Ranch 56 #1002H 377 602 3.9

Significant Production ≈ 2015 Timeframe

Wolfcamp Shale – Delaware Basin

NGLs33%

Typical DelawareWolfcamp

Gas36%

Oil31%

* Estimated potential reserves, not proved reserves.** See reconciliation schedule.

Midland Basin

Delaware Basin New

Mex

ico

Texa

s

Leonard

Wolfcamp Wolfcamp

EOG_0213-29

Increased Estimated Potential Reserves* From 65 MMBoe to 550 MMBoe, Net to EOG

Increased Estimated Reserves/Well to 500 MBoe, Gross; 400 MBoe, NAR

41 Net Hz Wells Drilled to Date

Typical Well Indicating More Oil- 50% of Total Potential Reserves Versus

Previous 41%

Target $5.5MM CWC - 55% Direct ATROR** 2012 Drilling Program

73,000 Net Acres- 16 Net Wells Planned in 2013

Recent Well Results – Peak Rates NGLs

Bopd + Bpd + McfdVaca 14 Fed #6H 1,290 255 1,420Diamond 8 FC #5H 1,162 183 1,017

* Estimated potential reserves, not proved reserves. Includes 27 MMBoe of proved reserves booked at December 31, 2012.** See reconciliation schedule.

Oil 50%

Gas 24%

NGLs26%

Typical Leonard Well

Leonard Shale – Delaware Basin

EOG_0213-30

* See reconciliation schedule.Note: 46 MMBoe proved reserves in the Wolfcamp Midland Basin booked at December 31, 2012.

133,000 Net Acres- 35 Net Wells Planned in 2013

Core Area Potential ≈ 430 MBoe/Well, Gross; 320 MBoe/Well, NAR - $5.3MM CWC Target

35% Direct ATROR* on 2013 Program

Recent Well Results – Peak Rates (Irion and Crockett)

Bopd + NGLs Bpd + McfdMiddle Wolfcamp Wells (10) 530 to 1,299 32 to 84 213 to 613 Lower Wolfcamp Wells (3) 632 to 1,290 45 to 102 325 to 737

Wolfcamp Shale – Midland Basin

Typical WolfcampMidland Basin Well

Gas 28%

NGLs30% Oil

42%

EOG_0213-31

* See reconciliation schedule.Note: 166 MMBoe proved reserves in Combo booked at December 31, 2012.

EOG is the Largest Oil Producer in the Barnett Combo

≈ 206,000 Net Acres in Core Area

≈ 3-Rig Program in 2013- Plan to Drill 130 Net Wells in 2013

Recent Strong Well IPsBopd + NGLs Bpd + Mcfd

Evans (3 Wells) 573 to 685 66 to 77 439 to 509

Revenues ≈ 89% Liquids Weighted, 46% Oil- 1st Year Revenues are 68% Oil

Typical Well ≈ 360 Mboe, Gross for $3.1 MM CWC- Cost Advantages Due to Self-Sourcing

of Frac Materials- ≈ 30% Direct ATROR* Even With Current

Ethane Prices

EOG-Owned Processing Plant Improves NGL Economics Combo Counties Gas Counties

Combo Core Area206,000 Net Acres

Ft. WorthFt. Worth

EOG Acreage

NGLs43%

NaturalGas11%

Combo RevenuesLife of Well

Oil46%

EOG_0213-32

United Kingdom

East Irish Sea (Conwy)- 20 MMBo Potential** Oil Discovery, 100% WI- First Production 4Q 2013- Estimated Peak Production – 20 MBopd, Net

* Based on mid-point full-year 2013 production estimates as of February 13, 2013.** Estimated potential reserves, not proved reserves. Includes 9 MMBo reserves booked at December 31, 2012.

TRINIDAD

ATLANTIC OCEAN

U(a)

Trinidad andTobago

VENEZUELA

4(a)

U(b)

SECC

NORTH SEA

United Kingdom

CentralGraben

SouthernGas Basin

EastIrishSea

YOY Production in 2013 vs. 2012 Decreases by ≈ 4%*- Current Drilling Program - Reduced Contract Takes

Trinidad

EOG_0213-33

EOG Reserves Within 5% of Independent Engineering Analysis Prepared by DeGolyer and MacNaughton- 25 Straight Years - Reviewed 87% of Proved Reserves for 2012

Conservative - Successful Efforts Accounting- Zero Goodwill- Credit Ratings – Moody’s A3 / S&P A-

2013 Dividend Increase – 10% to $0.75- 14 Increases in 14 Years

EOG_0213-34

Bbld $/Bbl2013 January 1 to June 30 105,000 $99.23

July 1 to December 31 93,000 $98.44

2013 150,000 MMBtud Hedged at $4.79

* As of February 13, 2013. See table with supporting data posted to EOG website, www.eogresources.com.** Based on the mid-point of full-year 2013 production estimates as of February 13, 2013.

2013 Crude Oil*

North American Natural Gas*

49%** Hedged at $98.85

EOG_0213-35

EOG Has Largest Proven U.S. Horizontal Drilling Oil Inventory in Entire Industry

EOG Has Captured Low-Cost, First-Mover Advantage – Key Differentiator

Horizontal Oil Assets Will Drive Strong 2013+ Production Growth- High Return Drilling Program- Have Multi-Year Drilling Inventory of Hz Oil/Liquids Plays

EOG’s Production Mix Has Changed, But Not Other Fundamentals- Focus on Maximizing Returns- Low Cost- Low Debt

Generating Strong Production, Profit and Cash Flow Results

Focus 2013 Operations on Crude Oil Drilling Activity

Copyright; Assumption of Risk: Copyright 2013. This presentation and the contents of this presentation have been copyrighted by EOG Resources, Inc. (EOG). All rights reserved. Copying of the presentation is forbidden without the prior written consent of EOG. Information in this presentation is provided "as is" without warranty of any kind, either express or implied, including but not limited to the implied warranties of merchantability, fitness for a particular purpose and the timeliness of the information. You assume all risk in using the information. In no event shall EOG or its representatives be liable for any special, indirect or consequential damages resulting from the use of the information.

Cautionary Notice Regarding Forward-Looking Statements: This presentation 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 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" 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 and unknown 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;• 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 developments around the world, including in the areas in which EOG operates;• the use of competing energy sources and the development of alternative energy sources;• the extent to which EOG incurs uninsured losses and liabilities or losses and liabilities in excess of its insurance coverage;• acts of war and terrorism and responses to these acts; and• the other factors described under Item 1A, "Risk Factors", on pages 15 through 23 of EOG's Annual Report on Form 10-K for the fiscal year ended December 31, 2011 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.

Oil and Gas Reserves; Non-GAAP Financial Measures: Effective January 1, 2010, 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 presentation 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, 2011, 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.