2015 Plan. Operations

Transcription

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2 2015 Plan Maintained Oil Production Guidance Lowered Capex Guidance by $200 Million Lowered LOE, G&A and Transportation Expense Guidance Increased Year-End Uncompleted Net Well Forecast to 320 from Drill 570 Net Wells and Complete 450 Net Wells in 2015 Operations Bakken Resource Estimate Update to 1.0 BnBoe* Increased by 600 MMBoe* - Decades of Drilling Inventory Reducing Costs Through Sustainable Efficiency Improvements Improving Well Productivity with Integrated Completions Technology - Exceeded 2Q 2015 Oil Production Forecast - Decline Rates Moderating Top Plays Generating Greater Than 35% ATROR** at $50 Oil Price * Estimated potential reserves net to EOG, not proved reserves. Includes proved reserves and prior production from existing wells. ** See reconciliation schedules. UBS_0915-1

3 Five Sustainable Advantages 1. High-Quality Assets With Scale 2. Innovation and Technology Focus 3. Low-Cost Operator 4. Organic Exploration Growth 5. Organization and Culture Uniquely Positioned to Improve Returns Year After Year UBS_0915-2

4 Direct ATROR* at Flat Oil Prices $50 Oil 35% Eagle Ford Bakken/Three Forks Core Delaware Basin Wolfcamp Delaware Basin 2 nd Bone Spring Sand Delaware Basin Leonard 95% Powder River Basin Wyoming DJ Basin 10% 25% Bakken/Three Forks Non-Core Midland Basin Wolfcamp $65 Oil Direct ATROR* Based on cash flow and time value of money: - Estimated Future Commodity Prices and Operating Costs - Costs Incurred to Drill, Complete and Equip a Well Excludes Indirect Capital: - Gathering, Processing and Other Midstream - Land, Seismic, Geological and Geophysical * See reconciliation schedules. Oil price is at the wellhead. UBS_0915-3

5 Play Eagle Ford Bakken/Three Forks Core Bakken/Three Forks Non-Core Delaware Basin Leonard Delaware Basin 2 nd Bone Spring Sand Delaware Basin Wolfcamp DJ Basin Powder River Basin Midland Basin Wolfcamp Net Acres 561, , ,000 80,000 90, ,000 85,000 63, ,000 1,400,000 Remaining Locations* 5, ,600 1, ,000 Drilling Years** Evaluating Resource Potential (MMBoe)*** 3, >20 Years of Drilling * Number of remaining net wells as of January 1, 2015 (Bakken/Three Forks as of July 1, 2015). Assumes no further downspacing, acreage additions or enhanced recovery. ** Assumes average of 2014 and 2015 number of well completions held flat. *** Estimated potential reserves net to EOG, not proved reserves. Includes proved reserves and prior production from existing wells. UBS_0915-4

6 Five Sustainable Advantages 1. High-Quality Assets With Scale 2. Innovation and Technology Focus 3. Low-Cost Operator 4. Organic Exploration Growth 5. Organization and Culture Uniquely Positioned to Improve Returns Year After Year UBS_0915-5

7 2010 Completions 540 Events /1,000 ft Contacting More Rock Near Wellbore 2015 Completions 4,030 Events /1,000 ft UBS_0915-6

8 Eagle Ford West Wells Average Cumulative Crude Oil Production* Eagle Ford West Completion Design 47 High-Density Wells* vs. 41 Low-Density Wells* 2014 Vintage Wells (Mbo) Cumulative Oil Production (Mbo) High-Density Wells Low-Density Wells +33% Producing Days Producing Days * Normalized to 5,300-foot lateral. * Normalized to 5,300-foot lateral. UBS_0915-7

9 Better Completions Downspacing Leonard Shale Cumulative Crude Oil Production* Leonard Shale Average Well Spacing (Feet) (Mbo) , Producing Days * Normalized to 4,500-foot lateral. UBS_0915-8

10 Eagle Ford Best Target Best Target UBS_0915-9

11 Five Sustainable Advantages 1. High-Quality Assets With Scale 2. Innovation and Technology Focus 3. Low-Cost Operator 4. Organic Exploration Growth 5. Organization and Culture Uniquely Positioned to Improve Returns Year After Year UBS_

12 Completed Well Cost* ($MM) Average Drilling Days* (Spud-to-TD) Plan Current Target Q15 Record * Normalized to 8,400 lateral. CWC = Drilling, Completion and Well-Site Facilities. UBS_

13 Completed Well Cost* ($MM) Average Drilling Days* (Spud-to-TD) Plan Current Target Current Record * Normalized to 5,300 lateral. CWC = Drilling, Completion and Well-Site Facilities. UBS_

14 $7.7 $6.5 $6.0 $ Average 2015 Plan Current Target * Normalized to 4,500 lateral. CWC = Drilling, Completion and Well-Site Facilities. UBS_

15 $14 $12 EOG Maintains Stable LOE Despite Rising Liquids Mix $10 LOE/Boe $8 $ E EOG Peers 2014 LOE $4 $2 $0 0% 10% 20% 30% 40% 50% 60% 70% 80% Liquids Production Source: Company filings. Peers: APA, APC, CHK, CLR, CXO, DVN, MRO, NBL, NFX, PXD, RRC and XEC. UBS_

16 Five Sustainable Advantages 1. High-Quality Assets With Scale 2. Innovation and Technology Focus 3. Low-Cost Operator 4. Organic Exploration Growth 5. Organization and Culture Uniquely Positioned to Improve Returns Year After Year UBS_

17 San Antonio Eagle Ford Reserve Potential* Since Discovery (BnBoe) 3.2 Crude Oil Window 2.2 Laredo Wet Gas Window Dry Gas Window Corpus Christi Miles EOG 624,000 Net Acres 561,000 Net Acres in Oil Window Apr 2010 Feb 2012 Feb 2013 Feb 2014 * Estimated potential reserves, not proved reserves. Includes 1,008 MMBoe proved reserves booked at December 31, UBS_

18 Canada Bakken/Three Forks Reserve Potential* (BnBoe) Elm Coulee State Line Stanley, ND Bakken Lite Bakken Core 1.0 Bakken Subcrop Antelope Extension Miles Core Non-Core EOG Acreage Bakken/Three Forks Bakken Oil Saturated * Estimated potential reserves, not proved reserves. Includes 219 MMBoe proved reserves booked at December 31, UBS_

19 EDDY LEA New Mexico Texas GAINES ANDREWS Delaware Basin Reserve Potential* (BnBoe) 1.35 Delaware Basin LOVING Central Basin Platform WINKLER CULBERSON WARD REEVES PECOS JEFF DAVIS 2010/ * Estimated potential reserves, not proved reserves. Includes 150 MMBoe proved reserves booked at December 31, UBS_

20 DJ Basin: Codell Sandstone and Niobrara Shale MMBoe* Powder River Basin: Parkman and Turner Sandstone MMBoe* Delaware Basin: Second Bone Spring Sandstone + 90,000 Net Acres, Evaluating Resource Continue Strong Exploration Efforts - Capturing Low-Cost Acreage * Estimated potential reserves, not proved reserves. Net to EOG. UBS_

21 Five Sustainable Advantages 1. High-Quality Assets With Scale 2. Innovation and Technology Focus 3. Low-Cost Operator 4. Organic Exploration Growth 5. Organization and Culture Uniquely Positioned to Improve Returns Year After Year UBS_

22 Legend Areas of Operation Offices Corporate Headquarters Decentralized Organization MAPS 8 Division Offices - 7 Domestic U.S. - 1 International Bottom-Up Value Creation Promotes Organic Exploration - Regional Expertise and Data Enhances Operations - Execution and Cost Reduction Return Driven - Compensation - Accountability UBS_

23 Compensation Factor Weightings: EOG Employees Are Incentivized to Deliver Returns Returns Production and Reserve Growth EOG 8% 30% Co. 1 15% 30% Co. 2 50% Co. 3 40% Co. 4 15% Co. 5 10% 36% Co. 6 33% Co. 7 15% Co. 8 25% Source: Company Reports. Percentages represent weightings applied in determining executive officer short-term incentive compensation. Peer Group: APA, APC, CHK, DVN, HES, MRO, NBL and PXD. UBS_

24 Five Sustainable Advantages 1. High-Quality Assets With Scale 2. Innovation and Technology Focus 3. Low-Cost Operator 4. Organic Exploration Growth 5. Organization and Culture Uniquely Positioned to Improve Returns Year After Year UBS_

25 Economics Today vs % 80% 90% 80% ATROR* 60% 40% 60% 45% 35% 50% 20% 0% Western Eagle Ford Delaware Basin Leonard $95 Oil $65 Oil $55 Oil * See reconciliation schedule. UBS_

26 On Track to Achieve 2015 Objectives Lower Finding and Operating Costs - Optimize Efficiencies in All Operations - Invest in Infrastructure to Lower Costs Six-Month Payouts - Capture Service Price Reductions Defer Production Growth - Reduce Rig Count and Delay Completions - Higher Returns and NPV - Preserve Capital Ready to Grow as Returns Improve - Uncompleted Well Inventory - Focus on High-Return Drilling: Eagle Ford, Delaware Basin and Bakken Seize Opportunities to Improve Competitive Position - Acquire High-Quality Acreage Leasing, Farm-In, Acquisitions - Continue Momentum Created by Organic Exploration Programs Generate High Returns at Low Oil Prices UBS_

27 EOG Positioned for Strong 2016 Performance Balanced Capex and Discretionary Cash Flow Few Capital Commitments in e.g. Rigs, International and Retention Drilling - Increased Flexibility Large High Quality DUC Inventory in Place - Sufficient Capital to Complete DUCs More Organic Growth Potential Positioned for Strong Returns DUC = Drilled, uncompleted well. UBS_

28 Copyright; Assumption of Risk: Copyright 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, 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, extent and duration 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 is successful in its efforts to economically develop its acreage in, produce reserves and achieve anticipated production levels from, and optimize 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, 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 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 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 13 through 20 of EOG s Annual Report on Form 10-K for the fiscal year ended December 31, 2014, 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: 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). 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, 2014, available from EOG at P.O. Box 4362, Houston, Texas (Attn: Investor Relations). You can also obtain this report from the SEC by calling SEC-0330 or from the SEC's website at In addition, reconciliation and calculation schedules for non-gaap financial measures can be found on the EOG website at