8-K 1 eog8k-0113guid.txt FORM 8-K UNITED STATES SECURITIES AND EXCHANGE COMMISSION WASHINGTON, D.C. 20549 FORM 8-K CURRENT REPORT Pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934 Date of Report: January 13, 2003 _______________ EOG RESOURCES, INC. (Exact name of registrant as specified in its charter) Delaware 1-9743 47-0684736 (State or other (Commission (I.R.S. Employer jurisdiction File Identification No.) of incorporation or Number) organization) 333 Clay Suite 4200 77002 Houston, Texas (Zip code) (Address of principal executive offices) 713/651-7000 (Registrant's telephone number, including area code) EOG RESOURCES, INC. Item 9. Regulation FD Disclosure I. Fourth Quarter 2002 Forecast The forecast items for fourth quarter 2002 set forth below for EOG Resources, Inc. (EOG) are based on current available information and expectations as of the date of this document, and replace the guidance for these items set forth in EOG's Current Report on Form 8-K filed October 21, 2002. Estimates are provided in the attached table which is incorporated by reference herein. II. 2003 Forecast EOG has not completed its capital budgeting and planning process for calendar year 2003. It is currently targeting total company production growth of approximately 5-6% per basic share for the full year 2003. III. Fourth Quarter 2002 Natural Gas and Crude Oil Financial Price Swap and Natural Gas Costless Collar Contracts Presented below is a summary of EOG's fourth quarter 2002 natural gas and crude oil financial price swap contracts and natural gas costless collar contracts. EOG accounts for these price swap and costless collar contracts using the mark-to-market accounting method. . Natural Gas Financial Price Swap Contracts EOG had price swap contracts in place, which are closed, covering notional volumes of 200,000 MMBtud at an average price of $3.13 per MMBtu for October 2002 and notional volumes of 75,000 MMBtud at an average price of $3.35 per MMBtu for November and December 2002. . Crude Oil Financial Price Swap Contract EOG had a price swap contract in place, which is closed, covering notional volumes of two thousand barrels of oil per day at a price of $21.50 per barrel for the period October 2002 through December 2002. . Natural Gas Costless Collar Contracts EOG had costless collar contracts in place covering notional volumes of 100,000 MMBtud with a floor price of $3.10 per MMBtu and ceiling prices that averaged $3.43 per MMBtu for October 2002. These contracts closed at a settlement price greater than the ceiling price. For the fourth quarter 2002, EOG anticipates a loss from outstanding mark-to-market commodity financial price swap and collar contracts of $7.1 million compared to a gain of $2.7 million for the prior year period. During the same period, net cash outflows from outstanding commodity price swap and collar contracts were $11.2 million, which included a $1.8 million premium payment in October 2002 for a 2003 collar contract, compared to net cash inflows of $34.3 million for the comparable period in 2001. IV. 2003 Natural Gas and Crude Oil Financial Price Swap and Natural Gas Collar Contracts Presented below is a summary of EOG's 2003 natural gas and crude oil financial price swap contracts and natural gas collar contracts. EOG accounts for these price swap and collar contracts using the mark-to-market accounting method. (a) Natural Gas Financial Price Swap Contracts Average Price Volume ($/MMBtu) (MMBtud) March $5.12 50,000 April $4.90 50,000 May $4.78 50,000 June $4.73 50,000 July $4.74 50,000 August $4.74 50,000 September $4.71 50,000 October $4.70 50,000 (b) Crude Oil Financial Price Swap Contracts Average Price Volume ($/Bbl) (Bbld) January $27.34 2,000 February $26.91 2,000 March $27.96 4,000 April $27.30 4,000 May $26.63 4,000 June $26.10 4,000 July $25.63 4,000 August $25.28 4,000 September $24.98 4,000 October $24.71 4,000 November $24.52 4,000 December $24.32 4,000 (c) Natural Gas Collar Contracts - Presented below are EOG's 2003 natural gas collar contracts and their respective volumes, with floor and ceiling prices expressed in $/MMBtu.
10,000 MMBtud 15,000 MMBtud 25,000 MMBtud Floor Price Ceiling Price Floor Price Ceiling Price Floor Price Ceiling Price February $4.22 $6.22 $4.30 $6.30 $4.19 $5.05 March $4.15 $6.15 $4.20 $6.20 $4.08 $5.00 April $4.01 $6.01 $4.02 $6.03 $3.88 $4.80 May $3.92 $5.92 $3.88 $5.89 $3.78 $4.70 June $3.89 $5.89 $3.89 $5.90 $3.78 $4.70 July $3.91 $5.91 $3.89 $5.90 $3.79 $4.73 August $3.91 $5.91 $3.91 $5.91 $3.79 $4.73 September $3.89 $5.89 $3.87 $5.87 $3.77 $4.73 October $3.90 $5.90 $3.87 $5.87 $3.77 $4.73 November $4.04 $6.04 $4.02 $6.03 $3.91 $4.90 December $4.18 $6.18 $4.15 $6.16 $4.04 $5.05
25,000 MMBtud 50,000 MMBtud* Floor Price Ceiling Price Floor Price Ceiling Price January - - $3.87 $6.09 February $4.22 $6.08 $3.76 $5.98 March $4.15 $6.01 $3.61 $5.83 April $4.01 $5.87 $3.59 $4.97 May $3.92 $5.78 $3.54 $4.92 June $3.89 $5.75 $3.56 $4.94 July $3.91 $5.77 $3.59 $4.97 August $3.91 $5.77 $3.60 $4.98 September $3.89 $5.75 $3.60 $4.98 October $3.90 $5.76 $3.60 $4.98 November $4.04 $5.90 $3.77 $5.15 December $4.18 $6.04 $3.92 $5.30 *Contract purchased at a premium of $0.10 per MMBtu, that was recognized in fourth quarter 2002 earnings and cash flows. The January portion of this contract closed at a settlement price within the price range without any first quarter 2003 financial impact.
IV. Forward-Looking Statements This document includes forward-looking statements within the meaning of Section 27A of the Securities Act of 1933 and Section 21E of the Securities Exchange Act of 1934. Forward-looking statements are not guarantees of performance. Although EOG believes its expectations reflected in forward-looking statements are based on reasonable assumptions, no assurance can be given that these expectations will be achieved. Important factors that could cause actual results to differ materially from the expectations reflected in the forward-looking statements include, among others: the timing and extent of changes in commodity prices for crude oil, natural gas and related products and interest rates; the extent and effect of any hedging activities engaged in by EOG; the extent of EOG's success in discovering, developing, marketing and producing reserves and in acquiring oil and gas properties; the accuracy of reserve estimates, which by their nature involve the exercise of professional judgment and may therefore be imprecise; political developments around the world, including terrorist activities and responses to terrorist activities; and financial market conditions. In light of these risks, uncertainties and assumptions, the events anticipated by EOG's forward-looking statements might not occur. EOG undertakes no obligations to update or revise its forward-looking statements, whether as a result of new information, future events or otherwise. Definitions $/Bbl US Dollars per barrel $/MMBtu US Dollars per million British thermal units $/Mcf US Dollars per thousand cubic feet $/Mcfe US Dollars per thousand cubic feet equivalent $MM US Dollars in millions Bbld Barrels per day MMBtu Million British thermal units MMBtud Million British thermal units per day MMcfd Million cubic feet per day Mbd Thousand barrels per day MM Millions NYMEX New York Mercantile Exchange WTI West Texas Intermediate SIGNATURE Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized. EOG RESOURCES, INC. Date: January 13, 2003 By: /s/ TIMOTHY K. DRIGGERS Timothy K. Driggers Vice President, Accounting and Land Administration (Principal Accounting Officer) EOG Resources, Inc. Estimated Ranges
4Q 2002 Daily Production Natural Gas (MMcfd) US 625 - 650 Canada 150 - 165 Trinidad 145 - 160 Total 920 - 975 Crude Oil (Mbd) US 17.0 - 19.0 Canada 1.5 - 2.5 Trinidad 2.0 - 2.9 Total 20.5 - 24.4 Natural Gas Liquids (Mbd) US 2.0 - 3.0 Canada 0.5 - 1.0 Total 2.5 - 4.0 Operating Costs Unit Costs ($/Mcfe) Lease and Well $0.45 - $0.48 Total Depreciation, Depletion and Amortization $0.98 - $1.02 Expenses ($MM) Exploration, Dry Hole and Impairment 60.0 - 70.0 General and Administrative 20.0 - 25.0 Capitalized Interest 1.9 - 2.3 Net Interest 14.0 - 16.0 Taxes Other than Income (% of Revenue) 6.0 - 7.2 Taxes Effective Rate 20% - 30% Deferred Ratio > 100% Preferred Dividends ($MM) 2.5 - 3.0 Shares Outstanding (MM) at December 31, 2002 Basic 114.4 Diluted (based on stock price of $39.92) 116.4 Capital Expenditures Excluding Acquisitions and Trinidad Ammonia Investments ($MM) - FY 2002 North America 700 - 740 International 30 - 50 Total 730 - 790 Pricing Natural Gas ($/Mcf) Differentials (include the effect of physical contracts) United States - below NYMEX Henry Hub $0.25 - $0.45 Canada - below NYMEX Henry Hub $0.50 - $0.70 Realizations Trinidad $1.15 - $1.25 Crude Oil ($/Bbl) Differentials US - below WTI $0.60 - $1.00 Canada - below WTI $2.50 - $3.75 Trinidad - below WTI $1.50 - $2.00