The Globe and Mail

Go to the Globe and Mail homepage

Jump to main navigationJump to main content

Press release from PR Newswire

EOG Resources Reports First Quarter 2010 Results

Monday, May 03, 2010

EOG Resources Reports First Quarter 2010 Results17:34 EDT Monday, May 03, 2010- Total Company Crude Oil Production Increased 25 Percent Year-Over-Year - On Track to Achieve 13 Percent Total Company Production Growth in 2010 - Realizing Strong, Consistent Results from Horizontal Crude Oil PlaysHOUSTON, May 3 /PRNewswire-FirstCall/ -- EOG Resources, Inc. (NYSE: EOG) (EOG) today reported first quarter 2010 net income of $118.0 million, or $0.46 per share. This compares to first quarter 2009 net income of $158.7 million, or $0.63 per share. The results for the first quarter 2010 included a $16.6 million ($9.9 million after tax, or $0.04 per share) revision in the estimated fair value of a contingent consideration liability associated with a previously disclosed acquisition of unproved acreage and a previously disclosed non-cash net gain of $7.8 million ($5.0 million after tax, or $0.02 per share) on the mark-to-market of financial commodity transactions. During the quarter, the net cash inflow related to financial commodity contracts was $23.0 million ($14.7 million after tax, or $0.06 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 quarter was $117.8 million, or $0.46 per share. Adjusted non-GAAP net income for the first quarter 2009 was $132.7 million, or $0.53 per share. (Please refer to the attached tables for the reconciliation of adjusted non-GAAP net income to GAAP net income.) �Operational Highlights and TargetsDriven primarily by production growth from its North Dakota Bakken and Fort Worth Basin Barnett Combo crude oil operations, EOG reported a 25 percent increase in crude oil production compared to the first quarter 2009.During the latter part of the first quarter, EOG began completing wells in the North Dakota Bakken following its winter drilling-only program. In the Parshall Field, the Van Hook 11-02H, in which EOG has 68 percent working interest, began production at 1,565 barrels of oil per day (Bopd). Also drilled in the Parshall Field, the Fertile 13-18H and Austin 23-32H began producing at 1,153 and 955 Bopd, respectively. EOG has 92 and 46 percent working interest in the wells, respectively. Outside of the Parshall Field in the Bakken Lite in Mountrail County, EOG drilled the Sidonia 18-14, which commenced production at 719 Bopd. EOG has 97 percent working interest in the well. EOG is operating 12 drilling rigs on its 580,000 net acre position in the North Dakota Bakken where it expects to average 32,500 barrels of oil equivalent per day (Boepd), net in 2010. �EOG completed several multi-well patterns in the Fort Worth Basin Barnett Combo using enhanced completion techniques. In Montague County, the three-well pattern of Alamo A Unit #1H, #2H and #3H was drilled on 55-acre spacing. The wells, in which EOG has 97 percent working interest, began production at a combined rate of over 900 Bopd with 2.4 million cubic feet of natural gas per day (MMcfd). Further assessing recovery efficiencies in one of the thickest parts of the formation in Cooke County, the Settle B# 1H was drilled horizontally in an area that had previously been tested with vertical wells. With an initial production rate of 1,852 Bopd and 3.7 MMcfd of liquids-rich natural gas, it is EOG's best well to date in the Barnett Combo. The successful test, in which EOG has 97 percent working interest, has set up new horizontal locations on its eastern acreage limits of Cooke County. �In the South Texas Eagle Ford where EOG holds 505,000 net acres in the mature oil window, the Harper Unit #4H was completed to sales in Karnes County. The well, the 17th that EOG has drilled across a six-county area in the play, began production at a rate of 602 Bopd with 650 thousand cubic feet per day of natural gas. EOG has 100 percent working interest in the well. To date, EOG's initial production results in the play are consistent with the average well commencing production at an approximate 800 Bopd rate. EOG is operating a six-rig drilling program in the Eagle Ford and plans to significantly increase production in 2011.In the Mid-Continent Cleveland Play where EOG had previously drilled vertical wells, it is now developing its 60,000-acre position with horizontal drilling and enhanced completion technology at economic rates of return. Recoverable reserves per well in this play have increased by a factor of four. In Lipscomb County, the Appel 438 #5H and #6H recently began producing at 1,000 and 840 Bopd with 2.5 and 1.0 MMcfd, respectively. EOG has 100 percent working interest in the wells."An overview of EOG's first quarter results reflect our progress in developing crude oil and natural gas liquids from our cadre of horizontal oil plays," said Mark G. Papa, Chairman and Chief Executive Officer. "With the strong liquids production growth that EOG is delivering, we are on track both to achieve our goal of total crude oil and natural gas liquids growth of 47 percent this year and further increase the liquids weighting of our production portfolio. We continue to target total company organic production growth of 13 percent for 2010."Capital StructureAt March 31, 2010, EOG's total debt outstanding was $2,797 million for a debt-to-total capitalization ratio of 22 percent. Taking into account cash on the balance sheet of $230 million, at the end of the quarter EOG's net debt was $2,567 million and the net debt-to-total capitalization ratio was 20 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).) To maintain a strong balance sheet with a low net debt-to-total capitalization ratio, EOG's goal is to generate cash proceeds by selling select North American natural gas producing assets or considering a joint venture transaction on certain natural gas shale properties by year-end 2010. � "EOG has a multi-year, high rate-of-return, liquids-rich drilling inventory. We plan to execute our drilling program and achieve our production growth targets while maintaining a strong balance sheet, with a net debt-to-total capitalization ratio at or below 25 percent. Given our liquids-driven total company production growth targets for the next three years of 13 percent, 19 percent and 21 percent combined with current NYMEX strip prices, we expect to be in a free cash flow position in 2012," Mr. Papa said. Conference Call Scheduled for May 4, 2010EOG's first quarter 2010 results conference call will be available via live audio webcast at 8 a.m. Central Daylight Time (9 a.m. Eastern Daylight Time) on Tuesday, May 4, 2010. To listen, log on to www.eogresources.com. The webcast will be archived on EOG's website through May 18, 2010.EOG Resources, Inc. is one of the largest independent (non-integrated) 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, including the accompanying forecast and benchmark commodity pricing information, 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 or generate income or cash flows 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 natural gas, crude oil and related commodities; changes in demand for natural gas, crude oil and related commodities, including ammonia and methanol;the extent to which EOG is successful in its efforts to discover and �market reserves and to acquire natural gas and crude oil properties; the extent to which EOG can optimize reserve recovery and economically develop its plays utilizing horizontal and vertical drilling and advanced completion technologies;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 natural gas and crude oil exploration and development projects, given the risks and uncertainties inherent in drilling, completing and operating natural gas and crude oil wells and the potential for interruptions of production, whether involuntary or intentional as a result of market or other conditions; 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; changes in government policies, laws and regulations, including environmental and tax laws and regulations;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;EOG's ability to obtain access to surface locations for drilling and production facilities; the extent to which EOG's third-party-operated natural gas and crude oil properties are operated successfully and economically;EOG's ability to effectively integrate acquired natural gas and crude oil 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;weather, including its impact on natural gas and crude oil 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;the accuracy of reserve estimates, which by their nature involve the exercise of professional judgment and may therefore be imprecise;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 extent and effect of any hedging activities engaged in by EOG;the timing and impact of liquefied natural gas imports;the use of competing energy sources and the development of alternative energy sources;the extent to which EOG incurs uninsured losses and liabilities;acts of war and terrorism and responses to these acts; andthe other factors described under Item 1A, "Risk Factors," on pages 14 through 19 of EOG's Annual Report on Form 10-K for the fiscal year ended December 31, 2009.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. Effective January 1, 2010, the United States Securities and Exchange Commission (SEC) now 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 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, 2009, 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. EOG RESOURCES, INC.FINANCIAL REPORT(Unaudited; in millions, except per share data)Three Months EndedMarch 31,20102009Net Operating Revenues$1,370.7$1,158.2Net Income $118.0$158.7Net Income Per Share Basic$0.47$0.64Diluted$0.46$0.63Average Number of Shares OutstandingBasic250.4248.0Diluted253.9250.2SUMMARY INCOME STATEMENTS(Unaudited; in thousands, except per share data)Three Months EndedMarch 31,20102009Net Operating RevenuesNatural Gas$676,982$567,578Crude Oil, Condensate and Natural Gas Liquids509,189200,328Gains on Mark-to-Market Commodity Derivative Contracts7,803351,383Gathering, Processing and Marketing171,94337,842Other, Net4,7761,078Total1,370,6931,158,209Operating ExpensesLease and Well165,992145,506Transportation Costs88,71168,862Gathering and Processing Costs15,66117,713Exploration Costs51,19749,623Dry Hole Costs23,0772,994Impairments 69,59565,471Marketing Costs168,76431,953Depreciation, Depletion and Amortization431,906389,329General and Administrative60,42357,946Taxes Other Than Income75,46547,400Total1,150,791876,797Operating Income219,902281,412Other Income, Net2,6831,739Income Before Interest Expense and Income Taxes222,585283,151Interest Expense, Net25,42818,376Income Before Income Taxes197,157264,775Income Tax Provision79,142106,065Net Income $118,015$158,710Dividends Declared per Common Share$0.155$0.145EOG RESOURCES, INC.OPERATING HIGHLIGHTS(Unaudited)Three Months EndedMarch 31,20102009Wellhead Volumes and PricesNatural Gas Volumes (MMcfd) (A)United States1,0431,193Canada211230Trinidad351263Other International (B)1616Total1,6211,702Average Natural Gas Prices ($/Mcf) (C)United States$5.24$4.06Canada5.224.43Trinidad2.511.32Other International (B)4.286.03Composite4.643.71Crude Oil and Condensate Volumes (MBbld) (A)United States54.144.9Canada5.83.2Trinidad3.83.0Other International (B)0.10.1Total63.851.2Average Crude Oil and Condensate Prices ($/Bbl) (C)United States$73.29$33.24Canada73.2737.11Trinidad66.4533.45Other International (B)71.3746.71Composite72.8733.51Natural Gas Liquids Volumes (MBbld) (A)United States23.721.7Canada0.91.1Total24.622.8Average Natural Gas Liquids Prices ($/Bbl) (C)United States$46.64$22.12Canada45.7825.52Composite46.6122.29Natural Gas Equivalent Volumes (MMcfed) (D)United States 1,5091,593Canada251255Trinidad374281Other International (B)1717Total2,1512,146Total Bcfe (D)193.6193.1(A) �Million cubic feet per day or thousand barrels per day, as applicable. � (B) �Other International includes EOG's United Kingdom and China operations. � (C) �Dollars per thousand cubic feet or per barrel, as applicable. � (D) �Million cubic feet equivalent per day or billion cubic feet equivalent, as applicable; includes natural gas, crude oil and condensate and natural gas liquids. �Natural gas equivalents are determined using the ratio of 6.0 thousand cubic feet of natural gas to 1.0 barrel of crude oil and condensate or natural gas liquids. Bcfe is calculated by multiplying the MMcfed amount by the number of days in the period and then dividing that amount by one thousand. � EOG RESOURCES, INC.SUMMARY BALANCE SHEETS(Unaudited; in thousands, except share data)March 31,2010December 31,2009ASSETSCurrent AssetsCash and Cash Equivalents$230,084$685,751Accounts Receivable, Net869,042771,417Inventories313,067261,723Assets from Price Risk Management Activities9,64420,915Income Taxes Receivable42,23037,009Deferred Income Taxes5,133-Other76,65762,726 � � Total1,545,8571,839,541Property, Plant and EquipmentOil and Gas Properties (Successful Efforts Method)25,725,20024,614,311Other Property, Plant and Equipment1,417,6631,350,132 � �Total Property, Plant and Equipment27,142,86325,964,443Less: �Accumulated Depreciation, Depletion and Amortization(10,325,928)(9,825,218) � �Total Property, Plant and Equipment, Net16,816,93516,139,225Other Assets146,276139,901Total Assets$18,509,068$18,118,667LIABILITIES AND STOCKHOLDERS' EQUITYCurrent LiabilitiesAccounts Payable$1,134,286$979,139Accrued Taxes Payable90,18292,858Dividends Payable38,76536,286Liabilities from Price Risk Management Activities40,34027,218Deferred Income Taxes20,65235,414Current Portion of Long-Term Debt37,00037,000Other131,784137,645 � � Total1,493,0091,345,560Long-Term Debt2,760,0002,760,000Other Liabilities635,239632,652Deferred Income Taxes3,455,9033,382,413Commitments and ContingenciesStockholders' EquityCommon Stock, $0.01 Par, 640,000,000 Shares Authorized: 253,120,631 Shares Issued at March 31, 2010 and 252,627,177 Shares Issued at December 31, 2009 202,531202,526Additional Paid In Capital620,367596,702Accumulated Other Comprehensive Income 405,234339,720Retained Earnings8,945,6488,866,747Common Stock Held in Treasury, 118,897 Shares at March 31, 2010 and 118,525 Shares at December 31, 2009(8,863)(7,653) � � �Total Stockholders' Equity10,164,9179,998,042Total Liabilities and Stockholders' Equity$18,509,068$18,118,667EOG RESOURCES, INC.SUMMARY STATEMENTS OF CASH FLOWS(Unaudited; in thousands)Three Months EndedMarch 31,20102009Cash Flows from Operating ActivitiesReconciliation of Net Income to Net Cash Provided by Operating Activities:Net Income $118,015$158,710Items Not Requiring (Providing) CashDepreciation, Depletion and Amortization431,906389,329Impairments 69,59565,471Stock-Based Compensation Expenses22,49426,407Deferred Income Taxes36,69583,215Other, Net(277)(652)Dry Hole Costs23,0772,994Mark-to-Market Commodity Derivative ContractsTotal Gains(7,803)(351,383)Realized Gains22,960310,964Excess Tax Benefits from Stock-Based Compensation-(4,688)Other, Net2,5052,940Changes in Components of Working Capital and Other Assets and LiabilitiesAccounts Receivable(95,770)156,926Inventories(53,312)(22,896)Accounts Payable147,632(352,622)Accrued Taxes Payable(3,790)19,166Other Assets(13,494)1,430Other Liabilities(5,554)(18,070)Changes in Components of Working Capital Associated with Investing and Financing Activities(74,592)138,598Net Cash Provided by Operating Activities620,287605,839Investing Cash FlowsAdditions to Oil and Gas Properties(1,063,390)(822,583)Additions to Other Property, Plant and Equipment(61,483)(65,013)Proceeds from Sales of Assets3,766447Changes in Components of Working Capital Associated with Investing Activities74,322(138,532)Other, Net7,107554Net Cash Used in Investing Activities(1,039,678)(1,025,127)Financing Cash FlowsNet Commercial Paper and Uncommitted Credit Facility Borrowings-208,100Dividends Paid(36,289)(33,491)Excess Tax Benefits from Stock-Based Compensation-4,688Treasury Stock Purchased(5,347)(4,904)Proceeds from Stock Options Exercised 5,2771,152Other, Net270(66)Net Cash (Used in) Provided by Financing Activities(36,089)175,479Effect of Exchange Rate Changes on Cash(187)(2,288)Decrease in Cash and Cash Equivalents(455,667)(246,097)Cash and Cash Equivalents at Beginning of Period685,751331,311Cash and Cash Equivalents at End of Period$230,084$85,214EOG RESOURCES, INC.QUANTITATIVE RECONCILIATION OF ADJUSTED NET INCOME (NON-GAAP) TO NET INCOME (GAAP)(Unaudited; in thousands, except per share data)The following chart adjusts three-month periods ended March 31, 2010 and 2009 reported Net Income (GAAP) to reflect actual net cash realized from financial commodity price transactions by eliminating the unrealized mark-to-market gains from these transactions and to eliminate the change in the estimated fair value of a contingent consideration liability related to EOG's previously disclosed acquisition of Haynesville and Bossier Shale unproved acreage. �EOG believes this presentation may be useful to investors who follow the practice of some industry analysts who adjust reported company earnings to match realizations to production settlement months and make certain other adjustments to exclude one-time items. �EOG management uses this information for comparative purposes within the industry.Three Months EndedMarch 31,2010 2009 Reported Net Income (GAAP)$118,015$158,710Mark-to-Market (MTM) Commodity Derivative Contracts ImpactTotal Gains(7,803)(351,383)Realized Gains22,960310,964 � Subtotal15,157(40,419)After Tax MTM Impact9,704(26,010)Less: �Change in Fair Value of Contingent Consideration Liability, Net of Tax(9,933)-Adjusted Net Income (Non-GAAP)$117,786$132,700Net Income Per Share (GAAP)Basic$0.47$0.64Diluted$0.46$0.63Adjusted Net Income Per Share (Non-GAAP)Basic$0.47$0.54Diluted$0.46$0.53Average Number of SharesBasic250,370247,991Diluted253,869250,204EOG RESOURCES, INC.QUANTITATIVE RECONCILIATION OF DISCRETIONARY CASH FLOW (NON-GAAP)TO NET CASH PROVIDED BY OPERATING ACTIVITIES (GAAP)(Unaudited; in thousands)The following chart reconciles three-month periods ended March 31, 2010 and 2009 Net Cash Provided by Operating Activities (GAAP) to Discretionary Cash Flow (Non-GAAP). �EOG believes this presentation may be useful to investors who follow the practice of some industry analysts who adjust Net Cash Provided by Operating Activities for Exploration Costs (excluding Stock-Based Compensation Expenses), Excess Tax Benefits from Stock-Based Compensation, Changes in Components of Working Capital and Other Assets and Liabilities, and Changes in Components of Working Capital Associated with Investing and Financing Activities. EOG management uses this information for comparative purposes within the industry.Three MonthsEnded March 31,20102009Net Cash Provided by Operating Activities (GAAP)$ 620,287$605,839AdjustmentsExploration Costs (excluding Stock-Based Compensation Expenses) 45,68344,471Excess Tax Benefits from Stock-Based Compensation-4,688Changes in Components of Working Capital and Other Assets and LiabilitiesAccounts Receivable95,770(156,926)Inventories53,31222,896Accounts Payable(147,632)352,622Accrued Taxes Payable3,790(19,166)Other Assets13,494(1,430)Other Liabilities5,55418,070Changes in Components of Working Capital Associated with Investing and Financing Activities74,592(138,598)Discretionary Cash Flow (Non-GAAP) $ 764,850$732,466EOG RESOURCES, INC.SECOND QUARTER AND FULL YEAR 2010 FORECAST AND BENCHMARK COMMODITY PRICING � � (a) �Second Quarter and Full Year 2010 ForecastThe forecast items for the second quarter and full year 2010 set forth below for EOG Resources, Inc. (EOG) are based on current available information and expectations as of the date of the accompanying press release. This forecast replaces and supersedes any previously issued guidance or forecast. � � (b) Benchmark Commodity PricingEOG bases United States and Canada natural gas price differentials upon the natural gas price at Henry Hub, Louisiana using the simple average of the NYMEX settlement prices for the last three trading days of the applicable month.EOG bases United States, Canada and Trinidad crude oil and condensate price differentials upon the West Texas Intermediate crude oil price at Cushing, Oklahoma using the simple average of the NYMEX settlement prices for each trading day within the applicable calendar month.ESTIMATED RANGES(Unaudited)2Q 2010Full Year 2010Daily ProductionNatural Gas Volumes (MMcfd)United States1,095-1,1251,150-1,190Canada190-200200-223Trinidad300-330280-315Other International12-1714-18Total1,597-1,6721,644-1,746Crude Oil and Condensate Volumes (MBbld)United States60.0-62.062.0-85.0Canada6.0-7.07.0-9.0Trinidad5.0-6.03.5-5.1Total71.0-75.072.5-99.1Natural Gas Liquids Volumes (MBbld)United States25.5-31.025.0-34.0Canada0.6-0.90.5-0.9Total26.1-31.925.5-34.9Natural Gas Equivalent Volumes (MMcfed)United States1,608-1,6831,672-1,904Canada230-247245-282Trinidad330-366301-346Other International12-1714-18Total2,180-2,3132,232-2,550ESTIMATED RANGES(Unaudited)2Q 2010Full Year 2010Operating CostsUnit Costs ($/Mcfe)Lease and Well$ � 0.76-$ � � � � 0.85$ � 0.77-$ � 0.82Transportation Costs$ � 0.39-$ � � � � 0.43$ � 0.39-$ � 0.42Depreciation, Depletion and Amortization$ � 2.27-$ � � � � 2.35$ � 2.28-$ � 2.38Expenses ($MM)Exploration, Dry Hole and Impairment$ 175.0-$ � � � 195.0$ 525.0-$ 675.0General and Administrative$ � 62.0$ � � � � 70.0$ 260.0$ 290.0Gathering and Processing $ � 14.5-$ � � � � 18.5$ � 53.0-$ � 75.0Capitalized Interest$ � 17.5-$ � � � � 21.5$ � 62.0-$ � 88.0Net Interest$ � 25.0-$ � � � � 30.0$ 112.0-$ 130.0Taxes Other Than Income (% of Revenue)6.5%-7.5%6.2%-7.0%Income TaxesEffective Rate 40%-50%35%-45%Current Taxes ($MM)$ � � �50-$ � � � � � �60$ � �185-$ � �205Capital Expenditures ($MM) - FY 2010 (Excluding Acquisitions)Exploration, Development, Gathering, Processing and OtherApproximately $ 5,100Pricing - (Refer to Benchmark Commodity Pricing in text)Natural Gas ($/Mcf)Differentials (include the effect of physical contracts)United States - below NYMEX Henry Hub$ � 0.12-$ � � � � 0.18$ � 0.10-$ � 0.20Canada - below NYMEX Henry Hub$ � 0.15-$ � � � � 0.35$ � 0.25-$ � 0.55RealizationsTrinidad$ � 1.60-$ � � � � 2.60$ � 1.60-$ � 2.60Other International$ � 3.00-$ � � � � 5.00$ � 3.00-$ � 5.00Crude Oil and Condensate ($/Bbl)DifferentialsUnited States - below WTI$ � 4.00-$ � � � � 9.00$ � 3.00-$ � 6.25Canada - below WTI$ � 6.75-$ � � � � 8.75$ � 5.00-$ � 8.00Trinidad - below WTI$ � 9.25-$ � � � 12.75$ � 8.65-$ 12.75Definitions$/BblU.S. Dollars per barrel$/McfU.S. Dollars per thousand cubic feet$/McfeU.S. Dollars per thousand cubic feet equivalent$MMU.S. Dollars in millionsMBbldThousand barrels per dayMMcfdMillion cubic feet per dayMMcfedMillion cubic feet equivalent per dayNYMEXNew York Mercantile ExchangeWTIWest Texas IntermediateEOG RESOURCES, INC.QUANTITATIVE RECONCILIATION OF NET DEBT (NON-GAAP) AND TOTAL CAPITALIZATION (NON-GAAP) AS USED IN THE CALCULATION OF THE NET DEBT-TO-TOTAL CAPITALIZATION RATIO (NON-GAAP)TO CURRENT AND LONG-TERM DEBT (GAAP) AND TOTAL CAPITALIZATION (GAAP)(Unaudited; in millions, except ratio data)The following chart reconciles Current and Long-Term Debt (GAAP) to Net Debt (Non-GAAP) and Total Capitalization (GAAP) to Total Capitalization (Non-GAAP), as used in the Net Debt-to-Total Capitalization ratio calculation. A portion of the cash is associated with international subsidiaries; tax considerations may impact debt paydown. EOG believes this presentation may be useful to investors who follow the practice of some industry analysts who utilize Net Debt and Total Capitalization (Non-GAAP) in their Net Debt-to-Total Capitalization ratio calculation. �EOG management uses this information for comparative purposes within the industry.March 31,2010Total Stockholders' Equity - (a)$10,165Current and Long-Term Debt - (b)2,797Less: Cash (230)Net Debt (Non-GAAP) - (c)2,567Total Capitalization (GAAP) - (a) + (b)$12,962Total Capitalization (Non-GAAP) - (a) + (c)$12,732Debt-to-Total Capitalization (GAAP) - (b) / [(a) + (b)]22%Net Debt-to-Total Capitalization (Non-GAAP) - (c) / [(a) + (c)]20%SOURCE EOG Resources, Inc.For further information: Investors, Maire A. Baldwin, +1-713-651-6EOG (651-6364), or Media and Investors, Elizabeth M. Ivers, +1-713-651-7132, both of EOG Resources, Inc.