-----BEGIN PRIVACY-ENHANCED MESSAGE----- Proc-Type: 2001,MIC-CLEAR Originator-Name: webmaster@www.sec.gov Originator-Key-Asymmetric: MFgwCgYEVQgBAQICAf8DSgAwRwJAW2sNKK9AVtBzYZmr6aGjlWyK3XmZv3dTINen TWSM7vrzLADbmYQaionwg5sDW3P6oaM5D3tdezXMm7z1T+B+twIDAQAB MIC-Info: RSA-MD5,RSA, Je+0st2j2pZShd/AGC9GUwbd5DjIUVh+fB4D6YdcrS/86uAw/q+XCzUiKGOaruO8 XBeLgAUeDvNuyNer2bfXQQ== 0000821189-04-000178.txt : 20040803 0000821189-04-000178.hdr.sgml : 20040803 20040803151809 ACCESSION NUMBER: 0000821189-04-000178 CONFORMED SUBMISSION TYPE: 10-Q PUBLIC DOCUMENT COUNT: 6 CONFORMED PERIOD OF REPORT: 20040630 FILED AS OF DATE: 20040803 FILER: COMPANY DATA: COMPANY CONFORMED NAME: EOG RESOURCES INC CENTRAL INDEX KEY: 0000821189 STANDARD INDUSTRIAL CLASSIFICATION: CRUDE PETROLEUM & NATURAL GAS [1311] IRS NUMBER: 470684736 STATE OF INCORPORATION: DE FISCAL YEAR END: 1231 FILING VALUES: FORM TYPE: 10-Q SEC ACT: 1934 Act SEC FILE NUMBER: 001-09743 FILM NUMBER: 04948239 BUSINESS ADDRESS: STREET 1: 333 CLAY SUITE 4200 CITY: HOUSTON STATE: TX ZIP: 77002-7361 BUSINESS PHONE: 7136517000 MAIL ADDRESS: STREET 1: 333 CLAY STREET SUITE 4200 CITY: HOUSTON STATE: TX ZIP: 77002-7361 FORMER COMPANY: FORMER CONFORMED NAME: ENRON OIL & GAS CO DATE OF NAME CHANGE: 19920703 10-Q 1 eog2q10q.txt FORM 10-Q SECURITIES AND EXCHANGE COMMISSION WASHINGTON, D. C. 20549 Form 10-Q x QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(D) OF THE SECURITIES EXCHANGE ACT OF 1934 For the quarterly period ended June 30, 2004 TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(D) OF THE SECURITIES EXCHANGE ACT OF 1934 Commission file number: 1-9743 EOG RESOURCES, INC. (Exact name of registrant as specified in its charter) Delaware 47-0684736 (State or other (I.R.S. Employer jurisdiction Identification No.) of incorporation or organization) 333 Clay Street, Suite 4200, Houston, Texas 77002-7361 (Address of principal executive offices) (zip code) Registrant's telephone number, including area code: 713-651-7000 Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. Yes x No Indicate by check mark whether the registrant is an accelerated filer (as defined in Rule 12b-2 of the Act). Yes x No Indicate the number of shares outstanding of each of the issuer's classes of common stock, as of July 23, 2004. Title of each class Number of shares Common Stock, $.01 117,850,517 par value EOG RESOURCES, INC. TABLE OF CONTENTS PART I. FINANCIAL INFORMATION Page No. ITEM 1. Financial Statements Consolidated Statements of Income - Three Months Ended June 30, 2004 and 2003 and Six Months Ended June 30, 2004 and 2003 3 Consolidated Balance Sheets - June 30, 2004 and December 31, 2003 4 Consolidated Statements of Cash Flows - Six Months Ended June 30, 2004 and 2003 5 Notes to Consolidated Financial Statements 6 ITEM 2. Management's Discussion and Analysis of Financial Condition and Results of Operations 13 ITEM 3. Quantitative and Qualitative Disclosures About Market Risk 24 ITEM 4. Controls and Procedures 24 PART II. OTHER INFORMATION ITEM 1. Legal Proceedings 25 ITEM 2. Changes in Securities and Use of Proceeds 25 ITEM 4. Submission of Matters to a Vote of Security Holders 25 ITEM 5. Other Information 26 ITEM 6. Exhibits and Current Reports on Form 8-K 26 SIGNATURES 27 EXHIBIT INDEX 28 PART I. FINANCIAL INFORMATION ITEM 1. FINANCIAL STATEMENTS EOG RESOURCES, INC. CONSOLIDATED STATEMENTS OF INCOME (In Thousands, Except Per Share Amounts) (Unaudited)
Three Months Ended Six Months Ended June 30, June 30, 2004 2003 2004 2003 Net Operating Revenues Natural Gas $430,532 $377,643 $847,921 $811,734 Crude Oil, Condensate and Natural Gas Liquids 102,401 61,471 192,859 136,979 Losses on Mark-to-Market Commodity Derivative Contracts (14,563) (15,753) (59,018) (60,974) Other, Net 651 1,393 1,579 1,684 Total 519,021 424,754 983,341 889,423 Operating Expenses Lease and Well 65,532 53,620 129,949 101,959 Exploration Costs 19,596 22,139 45,592 39,597 Dry Hole Costs 19,064 3,436 29,091 10,056 Impairments 15,711 25,475 33,359 37,431 Depreciation, Depletion and Amortization 116,224 106,587 230,021 210,140 General and Administrative 26,370 24,934 51,285 45,355 Taxes Other Than Income 29,788 11,695 65,872 41,888 Total 292,285 247,886 585,169 486,426 Operating Income 226,736 176,868 398,172 402,997 Other Income (Expense), Net 1,425 2,680 (1,304) 2,832 Income Before Interest Expense and Income Taxes 228,161 179,548 396,868 405,829 Interest Expense, Net 15,416 13,807 32,099 29,125 Income Before Income Taxes 212,745 165,741 364,769 376,704 Income Tax Provision 67,808 56,950 118,979 131,357 Net Income Before Cumulative Effect of Change in Accounting Principle 144,937 108,791 245,790 245,347 Cumulative Effect of Change in Accounting Principle, Net of Income Tax - - - (7,131) Net Income 144,937 108,791 245,790 238,216 Preferred Stock Dividends 2,758 2,758 5,516 5,516 Net Income Available to Common $142,179 $106,033 $240,274 $232,700 Net Income Per Share Available to Common Basic Net Income Available to Common Before Cumulative Effect of Change in Accounting Principle $ 1.22 $ 0.93 $ 2.07 $ 2.09 Cumulative Effect of Change in Accounting Principle, Net of Income Tax - - - (0.06) Net Income Available to Common $ 1.22 $ 0.93 $ 2.07 $ 2.03 Diluted Net Income Available to Common Before Cumulative Effect of Change in Accounting Principle $ 1.20 $ 0.91 $ 2.03 $ 2.06 Cumulative Effect of Change in Accounting Principle, Net of Income Tax - - - (0.06) Net Income Available to Common $ 1.20 $ 0.91 $ 2.03 $ 2.00 Average Number of Common Shares Basic 116,388 114,382 116,052 114,430 Diluted 118,709 116,131 118,227 116,212 The accompanying notes are an integral part of these consolidated financial statements.
PART I. FINANCIAL INFORMATION - (Continued) ITEM 1. FINANCIAL STATEMENTS - (Continued) EOG RESOURCES, INC. CONSOLIDATED BALANCE SHEETS (In Thousands, Except Share Data)
June 30, December 31, 2004 2003 (Unaudited) ASSETS Current Assets Cash and Cash Equivalents $ 67,839 $ 4,443 Accounts Receivable, Net 355,662 295,118 Inventories 30,253 21,922 Deferred Income Taxes 39,564 31,548 Other 57,106 42,983 Total 550,424 396,014 Oil and Gas Properties (Successful Efforts Method) 8,616,115 8,189,062 Less: Accumulated Depreciation, Depletion and Amortization (4,149,096) (3,940,145) Net Oil and Gas Properties 4,467,019 4,248,917 Other Assets 109,523 104,084 Total Assets $5,126,966 $4,749,015 LIABILITIES AND SHAREHOLDERS' EQUITY Current Liabilities Accounts Payable $ 319,535 $ 282,379 Accrued Taxes Payable 50,165 33,276 Dividends Payable 7,425 6,175 Liabilities from Price Risk Management Activities 58,601 37,779 Deferred Income Taxes 36,260 73,611 Other 34,078 43,299 Total 506,064 476,519 Long-Term Debt 1,085,822 1,108,872 Other Liabilities 180,743 171,115 Deferred Income Taxes 876,406 769,128 Shareholders' Equity Preferred Stock, $.01 Par, 10,000,000 Shares Authorized: Series B, 100,000 Shares Issued, Cumulative, $100,000 Liquidation Preference 98,707 98,589 Series D, 500 Shares Issued, Cumulative, $50,000 Liquidation Preference 49,918 49,827 Common Stock, $.01 Par, 320,000,000 Shares Authorized and 124,730,000 Shares Issued 201,247 201,247 Additional Paid in Capital 7,478 1,625 Unearned Compensation (27,978) (23,473) Accumulated Other Comprehensive Income 41,473 73,934 Retained Earnings 2,347,446 2,121,214 Common Stock Held in Treasury, 7,044,550 shares at June 30, 2004 and 8,819,600 shares at December 31, 2003 (240,360) (299,582) Total Shareholders' Equity 2,477,931 2,223,381 Total Liabilities and Shareholders' Equity $5,126,966 $4,749,015 The accompanying notes are an integral part of these consolidated financial statements.
PART I. FINANCIAL INFORMATION - (Continued) ITEM 1. FINANCIAL STATEMENTS - (Continued) EOG RESOURCES, INC. CONSOLIDATED STATEMENTS OF CASH FLOWS (In Thousands) (Unaudited)
Six Months Ended June 30, 2004 2003 Cash Flows From Operating Activities Reconciliation of Net Income to Net Cash Provided by Operating Activities: Net Income $ 245,790 $ 238,216 Items Not Requiring Cash Depreciation, Depletion and Amortization 230,021 210,140 Impairments 33,359 37,431 Deferred Income Taxes 84,216 79,975 Cumulative Effect of Change in Accounting Principle, Net of Income Tax - 7,131 Other, Net 13,289 3,965 Exploration Costs 45,592 39,597 Dry Hole Costs 29,091 10,056 Mark-to-Market Commodity Derivative Contracts Total Losses 59,018 60,974 Realized Losses (38,211) (39,089) Tax Benefits from Stock Options Exercised 13,792 4,802 Other, Net (1,273) 3,499 Changes in Components of Working Capital and Other Liabilities Accounts Receivable (60,458) (44,420) Inventories (8,331) (44) Accounts Payable 37,171 24,353 Accrued Taxes Payable (4,450) 16,809 Other Liabilities 257 (1,151) Other, Net (3,465) 7,899 Changes in Components of Working Capital Associated with Investing and Financing Activities 16,736 (6,931) Net Cash Provided by Operating Activities 692,144 653,212 Investing Cash Flows Additions to Oil and Gas Properties (534,540) (325,046) Exploration Costs (45,592) (39,597) Dry Hole Costs (29,091) (10,056) Proceeds from Sales of Assets 9,762 9,750 Changes in Components of Working Capital Associated with Investing Activities (15,988) 6,879 Other, Net (13,139) 1,279 Net Cash Used in Investing Activities (628,588) (356,791) Financing Cash Flows Long-Term Debt Borrowing 150,000 - Long-Term Debt Repayments (173,050) (134,310) Dividends Paid (18,099) (14,480) Treasury Stock Purchased - (21,295) Proceeds from Stock Options Exercised 43,190 14,730 Other, Net (2,201) 53 Net Cash Used in Financing Activities (160) (155,302) Increase in Cash and Cash Equivalents 63,396 141,119 Cash and Cash Equivalents at Beginning of Period 4,443 9,848 Cash and Cash Equivalents at End of Period $ 67,839 $ 150,967 The accompanying notes are an integral part of these consolidated financial statements.
PART I. FINANCIAL INFORMATION (Continued) ITEM 1. FINANCIAL STATEMENTS (Continued) EOG RESOURCES, INC. NOTES TO CONSOLIDATED FINANCIAL STATEMENTS 1. The consolidated financial statements of EOG Resources, Inc. (EOG) included herein have been prepared by management without audit pursuant to the rules and regulations of the Securities and Exchange Commission (SEC). Accordingly, they reflect all normal recurring adjustments which are, in the opinion of management, necessary for a fair presentation of the financial results for the interim periods. Certain information and notes normally included in financial statements prepared in accordance with accounting principles generally accepted in the United States of America have been condensed or omitted pursuant to such rules and regulations. However, management believes that the disclosures are adequate to make the information presented not misleading. These consolidated financial statements should be read in conjunction with the consolidated financial statements and the notes thereto included in EOG's Annual Report on Form 10-K for the year ended December 31, 2003 (EOG's 2003 Annual Report). The preparation of financial statements in conformity with accounting principles generally accepted in the United States of America requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates. Certain reclassifications have been made to prior period financial statements to conform with the current presentation. As more fully discussed in Note 12 to the consolidated financial statements included in EOG's 2003 Annual Report, EOG engages in price risk management activities from time to time. These activities are intended to manage EOG's exposure to fluctuations in commodity prices for natural gas and crude oil. EOG utilizes commodity derivative financial instruments, primarily price swaps and collars, as the means to manage this price risk. In addition to these financial transactions, EOG is a party to various physical commodity contracts for the sale of hydrocarbons that cover varying periods of time and have varying pricing provisions. The financial impact of these various physical commodity contracts is included in revenues at the time of settlement, which in turn affects average realized hydrocarbon prices. During the first six months of 2004 and 2003, EOG elected not to designate any of its commodity derivative financial contracts as accounting hedges, and accordingly, accounted for these commodity derivative financial contracts using the mark-to-market accounting method. EOG is exposed to foreign currency exchange rate risk inherent in its operations in foreign countries, including Canada, Trinidad and the United Kingdom. From time to time, EOG engages in exchange rate risk management activities to manage its exposure to exchange rates. Effective March 9, 2004, EOG entered into a foreign currency swap transaction with multiple banks to eliminate any exchange rate impacts that may result from the notes offered by one of the Canadian subsidiaries on the same date (see Note 8). EOG accounts for the foreign currency swap transaction using the hedge accounting method, pursuant to the provisions of Statement of Financial Accounting Standards (SFAS) No. 133 - "Accounting for Derivative Instruments and Hedging Activities," as amended by SFAS Nos. 137, 138 and 149. Under those provisions, as of June 30, 2004, EOG recorded the fair value of the swap of $2.7 million in Other Liabilities in the Liabilities section of the Consolidated Balance Sheets. Changes in the fair value of the foreign currency swap result in no net impact to the Consolidated Statements of Income and an after-tax loss of $1.7 million in Accumulated Other Comprehensive Income in the Shareholders' Equity section of the Consolidated Balance Sheets. On January 1, 2003, EOG adopted SFAS No. 143 - "Accounting for Asset Retirement Obligations" which essentially requires entities to record the fair value of a liability for legal obligations associated with the retirement of tangible long- lived assets and the associated asset retirement costs. The impact of adopting the statement was an after-tax charge of $7.1 million, which was reported in the first quarter of 2003 as cumulative effect of change in accounting principle. In December 2002, the Financial Accounting Standards Board (FASB) issued SFAS No. 148 - "Accounting for Stock-Based Compensation - Transition and Disclosure - an amendment of FASB Statement No. 123." This statement provides alternative methods of transition for a voluntary change to the fair value based method of accounting for stock-based employee compensation, along with the requirement of disclosure in both annual and interim financial statements about the method used and effect on reported results (see Note 7). On March 31, 2004, the FASB issued a proposed statement to amend SFAS No. 123 to require all companies to expense the value of employee stock options. This proposed statement set a comment deadline of June 30, 2004, and would be effective prospectively beginning first quarter of 2005 for EOG. EOG is currently evaluating the effect of the proposed statement on its financial statements and continues to monitor further developments relating to the proposed statement. During the third quarter of 2003, the SEC made comments to other registrants that oil and gas mineral rights acquired should be classified as an intangible asset pursuant to SFAS No. 141 - "Business Combinations," and SFAS No. 142 - "Goodwill and Other Intangible Assets." However, the SEC is not currently requiring all oil and gas producing companies to apply this classification or the disclosure requirements of intangible assets. Currently, EOG classifies the cost of oil and gas mineral rights as oil and gas properties and believes that this is consistent with oil and gas accounting and industry practice. The FASB has been asked to address this issue. If the FASB determines that the reclassification is required, EOG would reclassify these costs from oil and gas properties to intangible assets on the balance sheet. There would be no effect on the Consolidated Statements of Income or Consolidated Statements of Cash Flows. In March 2004, the FASB reached a consensus that for the mining industry all mineral rights are tangible assets and that SFAS Nos. 141 and 142 should be amended accordingly. In July 2004, the FASB set a comment deadline of August 17, 2004 to gather input as to whether the cost of oil and gas mineral rights is covered by the scope exception in SFAS No. 142 and, therefore, the current oil and gas accounting and industry practice is proper. EOG will continue to monitor the developments in this area until the final decision by the FASB emerges. On April 1, 2004, EOG adopted FASB Staff Position No. 106-2 - "Accounting and Disclosure Requirements related to the Medicare Prescription Drug, Improvement and Modernization Act of 2003" (FSP 106-2), which provides guidance on accounting for the effects of the Medicare Prescription Drug Improvement Act of 2003 for employers that sponsor postretirement health care plans that provide prescription drug benefits. The adoption of FSP 106-2 did not have a material impact on EOG's financial statements (see Note 7 - Postretirement Plan). 2. The following table sets forth the computation of net income per share available to common for the three-month and six-month periods ended June 30, 2004 and 2003 (in thousands, except per share amounts):
Three Months Ended Six Months Ended June 30, June 30, 2004 2003 2004 2003 Numerator for Basic and Diluted Earnings Per Share - Net Income Available to Common $142,179 $106,033 $240,274 $232,700 Denominator for Basic Earnings Per Share - Weighted Average Shares 116,388 114,382 116,052 114,430 Potential Dilutive Common Shares - Stock Options 1,867 1,509 1,734 1,531 Restricted Stock and Units 454 240 441 251 Denominator for Diluted Earnings Per Share - Adjusted Weighted Average Shares 118,709 116,131 118,227 116,212 Net Income Per Share of Common Stock Basic $ 1.22 $ 0.93 $ 2.07 $ 2.03 Diluted $ 1.20 $ 0.91 $ 2.03 $ 2.00
3. The following table presents the components of EOG's comprehensive income for the three-month and six-month periods ended June 30, 2004 and 2003 (in thousands):
Three Months Ended Six Months Ended June 30, June 30, 2004 2003 2004 2003 Comprehensive Income Net Income $144,937 $108,791 $245,790 $238,216 Other Comprehensive Income Foreign Currency Translation Adjustment (18,573) 48,167 (30,746) 87,423 Foreign Currency Swap Transaction, Net of Income Tax of $802 (1,715) - (1,715) - Total $124,649 $156,958 $213,329 $325,639
4. Selected financial information about operating segments is reported below for the three-month and six-month periods ended June 30, 2004 and 2003 (in thousands):
Three Months Ended Six Months Ended June 30, June 30, 2004 2003 2004 2003 Net Operating Revenues United States $388,258 $328,528 $723,026 $687,042 Canada 99,965 72,922 200,767 153,613 Trinidad 30,798 23,304 59,548 48,768 Total $519,021 $424,754 $983,341 $889,423 Operating Income (Loss) United States $152,113 $126,308 $253,118 $288,430 Canada 54,769 40,130 109,018 91,521 Trinidad 21,401 10,736 41,278 27,707 United Kingdom (1,547) (242) (5,242) (4,822) Other - (64) - 161 Total 226,736 176,868 398,172 402,997 Reconciling Items Other Income (Expense), Net 1,425 2,680 (1,304) 2,832 Interest Expense, Net 15,416 13,807 32,099 29,125 Income Before Income Taxes $212,745 $165,741 $364,769 $376,704
5. EOG and numerous other companies in the natural gas industry were named as defendants in various lawsuits alleging violations of the Civil False Claims Act in connection with the payment of royalties on natural gas and natural gas liquids produced on federal and Indian lands. EOG was involved in two of these lawsuits. The plaintiffs in one of the lawsuits dismissed EOG from that case without prejudice. EOG recently settled the second of these lawsuits for a nominal amount. EOG has been named as a potentially responsible party in certain Comprehensive Environmental Response Compensation and Liability Act proceedings. However, management does not believe that any potential assessments resulting from such proceedings will individually, or in the aggregate, have a material adverse effect on the financial condition or results of operations of EOG. There are various other lawsuits and claims against EOG that have arisen in the ordinary course of business. However, management does not believe these lawsuits and claims will individually, or in the aggregate, have a material adverse effect on the financial condition or results of operations of EOG. 6. The following table presents the reconciliation of the beginning and ending aggregate carrying amount of short-term and long-term legal obligations associated with the retirements of oil and gas properties pursuant to SFAS No. 143 for the three-month periods ended March 31 and June 30, 2004 (in thousands):
Asset Retirement Obligations Short-Term Long-Term Total Balance at December 31, 2003 $ 5,320 $118,624 $123,944 Liabilities Incurred 321 2,073 2,394 Liabilities Settled (97) (28) (125) Accretion 36 1,331 1,367 Foreign Currency Translation (3) (212) (215) Balance at March 31, 2004 5,577 121,788 127,365 Liabilities Incurred - 2,863 2,863 Liabilities Settled (748) (4,520) (5,268) Accretion 17 1,316 1,333 Foreign Currency Translation (10) (372) (382) Balance at June 30, 2004 $ 4,836 $121,075 $125,911
7. EOG has various stock plans (Plans) under which employees and non- employee members of the Board of Directors of EOG and its subsidiaries have been or may be granted certain equity compensation. Stock Options. EOG has in place compensatory stock option plans whereby participants have been or may be granted rights to purchase shares of common stock of EOG at a price not less than the market price of the stock at the date of grant. Employee Stock Purchase Plan. EOG has in place an employee stock purchase plan, pursuant to Section 423 of the Internal Revenue Code of 1986, as amended, whereby participants are granted rights to purchase shares of common stock of EOG at a price that is 15% less than the market price of the stock on either the first day or the last day of a six-month offering period, whichever is less. Pro Forma Information. EOG's pro forma net income available to common and net income per share available to common for the three- month and six-month periods ended June 30, 2004 and 2003, had compensation costs of stock options and the employee stock purchase plan been recorded using the fair value method in accordance with SFAS No. 123 - "Accounting for Stock-Based Compensation," as amended by SFAS No. 148 - "Accounting for Stock- Based Compensation - Transition and Disclosure - an amendment of FASB Statement No. 123," are presented below pursuant to the disclosure requirement of SFAS No. 148 (in millions, except per share amounts):
Three Months Ended Six Months Ended June 30, June 30, 2004 2003 2004 2003 Net Income Available to Common - As Reported $142.2 $106.0 $240.3 $232.7 Deduct: Total Stock-Based Employee Compensation Expense, Net of Income Tax (2.9) (2.3) (5.4) (5.6) Net Income Available to Common - Pro Forma $139.3 $103.7 $234.9 $227.1 Net Income per Share Available to Common Basic - As Reported $ 1.22 $ 0.93 $ 2.07 $ 2.03 Basic - Pro Forma $ 1.20 $ 0.91 $ 2.02 $ 1.98 Diluted - As Reported $ 1.20 $ 0.91 $ 2.03 $ 2.00 Diluted - Pro Forma $ 1.17 $ 0.89 $ 1.99 $ 1.95
The effects of applying SFAS No. 123, as amended, in this pro forma disclosure should not be interpreted as being indicative of future effects. SFAS No. 123 does not apply to awards prior to 1995 and the extent and timing of additional future awards cannot be predicted. Restricted Stock and Units. Under the Plans, employees may be granted restricted stock and/or units without cost to them. Related compensation expense for the three-month periods ended June 30, 2004 and 2003 was $2.4 million and $1.3 million, respectively. Related compensation expense for the six-month periods ended June 30, 2004 and 2003 was $4.4 million and $2.6 million, respectively. Pension Plans. EOG has a non-contributory defined contribution pension plan and a matched defined contribution savings plan in place for most of its employees in the United States. EOG's contributions to these plans are based on various percentages of compensation, and in some instances, are based upon the amount of the employees' contributions to the plan. For the three-month periods ended June 30, 2004 and 2003, the contributions to these plans amounted to approximately $2.7 million and $2.0 million, respectively. For the six-month periods ended June 30, 2004 and 2003, the contributions to these plans amounted to approximately $5.7 million and $3.9 million, respectively. In addition, EOG's Canadian subsidiary maintains a non- contributory defined contribution pension plan and a matched savings plan and EOG's Trinidadian subsidiary maintains a contributory defined benefit pension plan and a matched savings plan. These plans are available to most employees of the Canadian and Trinidadian subsidiaries, and contributions related to these plans were $222,000 and $149,000 for the three-month periods ended June 30, 2004 and 2003, respectively. Contributions related to these plans were $427,000 and $285,000 for the six-month periods ended June 30, 2004 and 2003, respectively. Postretirement Plan. During 2000, EOG adopted postretirement medical and dental benefits for eligible employees and their eligible dependents. Benefits are provided under the provisions of a contributory defined dollar benefit plan. EOG accrues these postretirement benefit costs over the service lives of the employees expected to be eligible to receive such benefits. The following table summarizes EOG's postretirement benefit expense for the three-month and six-month periods ended June 30, 2003 and 2004 (in thousands):
Three Months Ended Six Months Ended June 30, June 30, 2004 2003 2004 2003 Service Cost $ 36 $ 44 $106 $ 88 Interest Cost 29 32 79 64 Expected Return on Plan Assets - - - - Amortization of Prior Service Cost 32 19 65 38 Amortization of Net Actuarial (Gain) Loss (18) - (18) - Net Periodic Benefit Cost $ 79 $ 95 $232 $190
EOG previously disclosed in its financial statements for the year ended December 31, 2003, that it expected to contribute $57,000 to its postretirement plan in 2004. As of June 30, 2004, $29,000 of contributions have been made. EOG presently anticipates contributing an additional $28,000 to fund its postretirement plan in 2004 for a total of $57,000. 8. On March 9, 2004, EOG Resources Canada Inc., a wholly owned subsidiary of EOG, issued notes with a total principal amount of US$150 million, an annual interest rate of 4.75% and a maturity date of March 15, 2014, under Rule 144A of the Securities Act of 1933, as amended. The notes are guaranteed by EOG. In conjunction with the offering, EOG entered into a foreign currency swap transaction with multiple banks for the equivalent amount of the notes and related interest, which has in effect converted this indebtedness into CAD$201.3 million with a 5.275% interest rate. PART I. FINANCIAL INFORMATION (Continued) ITEM 2. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS EOG RESOURCES, INC. Overview EOG Resources, Inc. (EOG) is one of the largest independent (non-integrated) oil and gas companies in the United States and has substantial proved reserves in the United States, Canada, offshore Trinidad and, to a lesser extent, the United Kingdom North Sea. EOG operates under a business strategy that focuses predominantly on three factors: achieving a strong reinvestment rate of return on its capital program, drilling internally generated prospects in order to find and develop low cost reserves, and maintaining a strong balance sheet, with a below industry average debt-to-total capitalization ratio. Operations United States and Canada. EOG's effort to identify plays with larger reserve potential has proven a successful supplement to its base development and exploitation program in the United States and Canada. EOG plans to continue to drill smaller wells in large acreage plays, which, in the aggregate, will contribute substantially to EOG's crude oil and natural gas production. EOG has several larger potential plays under way in Wyoming, Utah and Texas, including the Barnett Shale. To date, EOG has leased approximately 258,000 net acres in the non-core Barnett Shale area (with the core area defined primarily as western Denton and eastern Wise counties). While EOG has continued to drill successful wells in the Barnett Shale through the use of 3-D seismic and horizontal drilling techniques, significant production growth or reserve additions are not anticipated from the Barnett Shale until 2005 and beyond. In South Texas, EOG has continued its success in the Roleta and Frio Formations. Through the use of 3-D seismic, EOG has expanded the inventory of drilling locations in the Roleta Formation and also expects to continue an active drilling program in the Frio Formation. International. In Trinidad, EOG drilled two development wells at its Parula Discovery. Production from these wells will be among the sources to supply existing gas contracts, as well as feeding the new methanol plant that is scheduled to commence operations in 2005. EOG recently completed an additional development well on the U(a) Block which will primarily supply natural gas to the Caribbean Nitrogen Company Limited (CNCL) and the Nitrogen (2000) Unlimited (N2000) ammonia plants. The N2000 plant has commenced commissioning operations ahead of schedule and is expected to achieve full plant productivity in August 2004. Although EOG continues to focus on United States and Canadian natural gas, EOG sees an increasing linkage between United States and Canadian natural gas demand and Trinidadian natural gas supply. For example, liquefied natural gas (LNG) imports from existing and planned facilities in Trinidad are serious contenders to meet increasing United States demand. In addition, ammonia, methanol and chemical production has been relocating from the United States and Canada to Trinidad, driven by attractive natural gas feedstock prices in the island nation. EOG anticipates that its existing position with the supply contracts to the two ammonia plants and the new methanol plant will continue to give its portfolio an even broader exposure to United States and Canadian natural gas fundamentals. In EOG's new venue in the Southern Gas Basin of the United Kingdom North Sea, EOG is on track to commence production of approximately 40 MMcfd, net, from its two gas discoveries by the end of 2004. These wells were farm-in opportunities from major oil companies. EOG is reviewing additional farm-in opportunities in this area and expects to participate in at least one more exploration well in 2004. EOG expects to begin operatorship in the United Kingdom later in 2004. Capital Structure As noted, one of management's key strategies is to keep a strong balance sheet with a consistently below industry average debt-to-total capitalization ratio. During the first half of 2004, EOG reduced debt by $23 million and increased its cash position by $63 million. At June 30, 2004, its debt-to-total capitalization ratio was 30.5%, down from 33.3% at December 31, 2003. On March 9, 2004, EOG Resources Canada Inc., a wholly owned subsidiary of EOG, issued notes with a total principal amount of US$150 million. The proceeds from these notes, along with the cash provided from operating activities, allowed EOG to fund its entire first half of 2004 capital program of $609 million and pay down $98 million on outstanding commercial paper borrowings and $75 million on a senior unsecured term loan facility. As management currently assesses price forecast and demand trends for the remainder of 2004, EOG continues to believe that operations and capital expenditure activity can be funded by cash generated from operations and, if needed, available financing alternatives. For 2004, EOG's current estimated capital expenditure budget increased from approximately $1.1 billion to approximately $1.3 billion, excluding acquisitions. EOG plans to spend about 5% of this estimated capital expenditure budget to drill new, internally generated, bigger target ideas. United States and Canadian natural gas continues to be a key component of this effort. When it fits EOG's strategy, EOG will make acquisitions that bolster existing drilling programs or offer EOG incremental exploration and/or production opportunities. Management believes that EOG has one of the strongest overall drilling inventories in EOG's history. Results of Operations The following review of operations for the three-month periods ended June 30, 2004 and 2003 should be read in conjunction with the consolidated financial statements of EOG and notes thereto. Net Operating Revenues During the second quarter of 2004, net operating revenues increased $94 million to $519 million. Total wellhead revenues of $533 million increased $94 million, or 21%, as compared to a year ago. Wellhead volume and price statistics for the three- month periods ended June 30, 2004 and 2003 were as follows:
Three Months Ended June 30, 2004 2003 Natural Gas Volumes (MMcf per day)(1) United States 619 636 Canada 197 153 United States and Canada 816 789 Trinidad 162 148 Total 978 937 Average Natural Gas Prices ($/Mcf)(2) United States $5.67 $5.06 Canada 5.04 4.77 United States and Canada Composite 5.52 5.00 Trinidad 1.36 1.32 Composite 4.83 4.42 Crude Oil and Condensate Volumes (MBbl per day)(1) United States 21.0 17.3 Canada 2.6 2.3 United States and Canada 23.6 19.6 Trinidad 3.1 2.3 Total 26.7 21.9 Average Crude Oil and Condensate Prices ($/Bbl)(2) United States $37.39 $28.18 Canada 35.59 27.00 United States and Canada Composite 37.19 28.04 Trinidad 37.69 26.31 Composite 37.25 27.86 Natural Gas Liquids Volumes (MBbl per day)(1) United States 5.0 3.0 Canada 0.6 0.4 Total 5.6 3.4 Average Natural Gas Liquids Prices ($/Bbl)(2) United States $23.78 $19.63 Canada 20.35 14.15 Composite 23.40 19.00 Natural Gas Equivalent Volumes (MMcfe per day)(3) United States 775 757 Canada 216 170 United States and Canada 991 927 Trinidad 181 162 Total 1,172 1,089 Total Bcfe(3) Deliveries 106.6 99.1 (1) Million cubic feet per day or thousand barrels per day, as applicable. (2) Dollars per thousand cubic feet or per barrel, as applicable. (3) Million cubic feet equivalent per day or billion cubic feet equivalent, as applicable.
Wellhead natural gas revenues for the second quarter of 2004 increased $53 million, or 14%, due to the increase in the composite average wellhead natural gas price ($37 million) and the increase in natural gas deliveries ($16 million). The composite average wellhead price for natural gas increased 9% to $4.83 per Mcf for the second quarter of 2004 from $4.42 per Mcf for the same period of 2003. Natural gas deliveries increased 41 MMcf per day, or 4%, to 978 MMcf per day for the second quarter of 2004 from 937 MMcf per day for the comparable period in 2003, primarily due to a 44 MMcf per day, or 29%, increase in Canada and a 14 MMcf per day, or 9%, increase in Trinidad, partially offset by a 17 MMcf per day, or 3%, decline in the United States. The increase in Canada was attributable to the property acquisitions in the fourth quarter of 2003 (32 MMcf per day) and additional production from drilling activities (17 MMcf per day), partially offset by a temporary plant shutdown (5 MMcf per day). The increase in Trinidad was attributable to the Parula wells on the SECC block beginning production in February 2004 (17 MMcf per day), partially offset by the decreased production from the U(a) block as a result of a temporary ammonia plant shutdown in May 2004 (5 MMcf per day). Wellhead crude oil and condensate revenues increased $35 million, or 63%, due to increases in both the composite average wellhead crude oil and condensate price ($23 million) and the wellhead crude oil and condensate deliveries ($12 million). The composite average wellhead crude oil and condensate price for the second quarter of 2004 was $37.25 per barrel compared to $27.86 per barrel for the same period of 2003. Wellhead crude oil and condensate deliveries increased 4.8 MBbl per day, or 22%, to 26.7 MBbl per day for the second quarter of 2004. The increase was mainly from the production from new wells in the United States (3.7 MBbl per day) and from higher production from the Parula wells in Trinidad (0.9 MBbl per day). Natural gas liquids revenues were $6 million higher than a year ago primarily due to increases in deliveries ($4 million) and the composite average price ($2 million). During the second quarter of 2004, EOG recognized a loss on mark- to-market financial commodity derivative contracts of $15 million compared to a loss of $16 million for the same period in 2003. During the second quarter of 2004, net cash outflow related to settled natural gas financial collar contracts and settled natural gas and crude oil financial price swap contracts was $36 million compared to a net cash outflow of $11 million for the same period in 2003. Operating and Other Expenses For the second quarter of 2004, operating expenses of $292 million were $44 million higher than the $248 million incurred in the second quarter of 2003. The following table presents the costs per Mcfe for the three-month periods ended June 30, 2004 and 2003:
Three Months Ended June 30, 2004 2003 Lease and Well $0.61 $0.54 DD&A 1.09 1.08 General and Administrative (G&A) 0.25 0.25 Taxes Other than Income 0.28 0.12 Interest Expense, Net 0.15 0.14 Total Per-Unit Costs(1) $2.38 $2.13 (1) Total per-unit costs do not include exploration costs, dry hole costs and impairments.
The higher per-unit costs of lease and well, depreciation, depletion and amortization (DD&A), taxes other than income and net interest expense for the three-month period ended June 30, 2004 compared to the same period in 2003 were due primarily to the reasons set forth below. Lease and well expenses of $66 million were $12 million higher than the prior year period due primarily to a general increase in service costs related to operating activities in the United States ($4 million), increased transportation expense in the United States ($3 million), increased production in Canada ($3 million) and in the United States ($1 million), and changes in the Canadian exchange rate ($1 million). DD&A expenses of $116 million increased $10 million from the prior year period due primarily to increased production in Canada ($4 million) and in the United States ($2 million), increased United States DD&A rates ($2 million) and increased Canadian DD&A rates ($1 million). Taxes other than income of $30 million were $18 million higher than the prior year period due primarily to $17 million in retroactive credits against severance taxes resulting from the qualification of additional wells for a Texas high cost gas severance tax exemption recorded in the second quarter of 2003 versus $1 million recorded in the second quarter of 2004. Net interest expense of $15 million increased $2 million compared to the second quarter of 2003 primarily due to a slightly higher average debt balance. Exploration costs of $20 million were $3 million lower than a year ago due primarily to a major seismic acquisition program in Trinidad ($4 million) which began in the second quarter of 2003, partially offset by increased geological and geoscience expenditures in the United States ($1 million). Impairments of $16 million decreased $10 million compared to the prior year period due to lower amortization of unproved leases in the United States ($4 million) and lower impairments to the carrying value of certain long-lived assets as a result of downward revisions in the future cash flow analysis for certain properties in the United States ($6 million). Total impairments under Statement of Financial Accounting Standards No. 144 - "Accounting for the Impairment or Disposal of Long-Lived Assets" for the second quarter of 2004 and 2003 were $2 million and $8 million, respectively. For the second quarter of 2004, the income tax provision of $68 million increased $11 million compared to the second quarter of 2003, primarily due to higher income before income taxes ($17 million) and higher effective foreign income tax rates ($3 million), partially offset by lower deferred income taxes associated with a reduction in the Alberta (Canada) corporate tax rate ($5 million) and decreases in other adjustments ($4 million). The net effective tax rate for the second quarter of 2004 decreased to 32% from 34% for the same period of 2003. Results of Operations Net Operating Revenues During the first half of 2004, net operating revenues increased $94 million to $983 million. Total wellhead revenues of $1,040 million increased $92 million, or 10%, as compared to a year ago. Wellhead volume and price statistics for the six-month periods ended June 30, 2004 and 2003 were as follows:
Six Months Ended June 30, 2004 2003 Natural Gas Volumes (MMcf per day) United States 618 639 Canada 201 155 United States and Canada 819 794 Trinidad 158 152 Total 977 946 Average Natural Gas Prices ($/Mcf) United States $5.54 $5.49 Canada 5.01 4.97 United States and Canada Composite 5.41 5.39 Trinidad 1.42 1.32 Composite 4.77 4.74 Crude Oil and Condensate Volumes (MBbl per day) United States 20.5 17.8 Canada 2.6 2.2 United States and Canada 23.1 20.0 Trinidad 2.8 2.4 Total 25.9 22.4 Average Crude Oil and Condensate Prices ($/Bbl) United States $36.11 $30.63 Canada 33.63 29.26 United States and Canada Composite 35.83 30.48 Trinidad 35.52 29.82 Composite 35.80 30.41 Natural Gas Liquids Volumes (MBbl per day) United States 4.9 3.1 Canada 0.6 0.5 Total 5.5 3.6 Average Natural Gas Liquids Prices ($/Bbl) United States $24.24 $21.46 Canada 20.25 19.22 Composite 23.80 21.13 Natural Gas Equivalent Volumes (MMcfe per day) United States 771 764 Canada 219 172 United States and Canada 990 936 Trinidad 175 166 Total 1,165 1,102 Total Bcfe Deliveries 212.1 199.4
During the first half of 2004, wellhead natural gas revenues increased 4% to $847 million from $811 million for the same period of 2003. The increase was due to the increase in natural gas deliveries ($31 million) and the increase in the composite average wellhead natural gas price ($5 million). The composite average wellhead price for natural gas increased to $4.77 per Mcf from $4.74 per Mcf for the comparable period a year ago. Natural gas deliveries increased 31 MMcf per day, or 3%, to 977 MMcf per day for the first half of 2004 from 946 MMcf per day a year ago, primarily due to a 46 MMcf per day, or 30%, increase in Canada and a 6 MMcf per day, or 4%, increase in Trinidad, partially offset by a 21 MMcf per day, or 3%, decline in the United States. The increase in Canada was attributable to the property acquisitions in the fourth quarter of 2003 (32 MMcf per day) and additional production from drilling activities (17 MMcf per day), offset by a temporary plant shutdown (3 MMcf per day). The increase in Trinidad was attributable to the Parula wells on the SECC block beginning production in February 2004 (9 MMcf per day). Wellhead crude oil and condensate revenues for the first half of 2004 increased $46 million, or 37%, as compared to the prior year same period, due to the increases in both the average wellhead crude oil and condensate prices ($26 million) and crude oil and condensate deliveries ($20 million). The composite average wellhead price for crude oil and condensate increased 18% to $35.80 per barrel from $30.41 per barrel for the comparable period a year ago. Wellhead crude oil and condensate deliveries increased 3.5 MBbl per day, or 16%, to 25.9 MBbl per day for the first half of 2004 from 22.4 MBbl per day a year ago. The increase was mainly due to the production from new wells in the United States (2.7 MBbl per day) and production from the Parula wells on the SECC block commencing in February 2004 in Trinidad (0.5 MBbl per day). Natural gas liquids revenues were $10 million higher than a year ago primarily due to increases in deliveries ($7 million) and the composite average price ($3 million). During the first six months of 2004, EOG recognized a loss on mark- to-market financial commodity derivative contracts of $59 million compared to a loss of $61 million for the same period in 2003. During the first six months of 2004, net cash outflow related to settled natural gas financial collar contracts and settled natural gas and crude oil financial price swap contracts was $38 million compared to a net cash outflow of $39 million for the same period in 2003. Operating and Other Expenses For the first six months of 2004, operating expenses of $585 million were $99 million higher than the $486 million incurred in the first six months of 2003. The following table presents the costs per Mcfe for the six-month periods ended June 30, 2004 and 2003:
Six Months Ended June 30, 2004 2003 Lease and Well $0.61 $0.51 DD&A 1.09 1.05 G&A 0.24 0.23 Taxes Other than Income 0.31 0.21 Interest Expense, Net 0.15 0.15 Total Per-Unit Costs(1) $2.40 $2.15 (1) Total per-unit costs do not include exploration costs, dry hole costs and impairments.
The higher per-unit costs of lease and well, DD&A, G&A, taxes other than income and net interest expense for the six-month period ended June 30, 2004 compared to the same period in 2003 were due primarily to the reasons set forth below. Lease and well expenses of $130 million were $28 million higher than the prior year period due primarily to a general increase in service costs related to operating activities in the United States ($9 million) and Canada ($1 million), increased transportation expense in the United States ($7 million) and in Canada ($1 million), increased production in Canada ($6 million) and changes in the Canadian exchange rate ($3 million). DD&A expenses of $230 million increased $20 million from the prior year period due primarily to increased production in Canada ($8 million), changes in the Canadian exchange rate ($3 million), increased Canadian DD&A rates ($3 million) from acquiring and developing reserves and increased United States DD&A rates ($3 million) due to a gradual proportional increase in production from higher cost properties. G&A expenses of $51 million were $6 million higher than the comparable prior year period due primarily to expanded operations. Taxes other than income of $66 million were $24 million higher than the prior year period due primarily to $18 million in retroactive credits against severance taxes resulting from the qualification of additional wells for a Texas high cost gas severance tax exemption recorded in the first half of 2003 versus $2 million recorded in the first half of 2004 and the results of a production tax lawsuit expensed in the first quarter of 2004 ($5 million). Net interest expense of $32 million increased $3 million compared to the same period of 2003 primarily due to an interest charge related to the results of a production tax lawsuit in the first quarter of 2004 ($2 million) and a slightly higher average debt balance ($1 million). Exploration costs of $46 million were $6 million higher than a year ago due primarily to increased geological and geoscience expenditures in the United States ($9 million) and Canada ($1 million), partially offset by a decrease in geological and geoscience expenditures in Trinidad due primarily to a major seismic acquisition program in Trinidad ($4 million) which began in the second quarter of 2003. Impairments decreased $4 million to $33 million compared to the comparable prior year period due to lower amortization of unproved leases in the United States ($1 million) and lower impairments to the carrying value of certain long-lived assets as a result of downward revisions in the future cash flow analysis for certain properties in the United States ($3 million). Total impairments under Statement of Financial Accounting Standards No. 144 - "Accounting for the Impairment or Disposal of Long-Lived Assets" for the first six months of 2004 and 2003 were $5 million and $8 million, respectively. For the first six months of 2004, the income tax provision of $119 million decreased $12 million compared to the first six months of 2003, primarily due to lower income before income taxes ($5 million), lower deferred income taxes associated with a reduction in the Alberta (Canada) corporate tax rate ($5 million) and decreases in other adjustments ($5 million), partially offset by higher effective foreign tax rates ($3 million). The net effective tax rate for the first six months of 2004 decreased to 33% from 35% for the same period of 2003. Capital Resources and Liquidity Cash Flows At June 30, 2004 and December 31, 2003, EOG had cash and cash equivalents of $68 million and $4 million, respectively. The primary sources of cash for EOG during the first half of 2004 included funds generated from operations, proceeds from sales of assets, proceeds from new borrowings (see discussion on the US$150 million notes issuance below) and proceeds from stock options exercised. Primary cash outflows included funds used in operations, exploration and development expenditures, repayment of debt and payment of dividends to shareholders. Cash provided by operating activities of $692 million for the first six months of 2004 increased $39 million as compared to the same period in 2003 primarily reflecting higher wellhead revenues ($92 million), partially offset by higher cash operating expenses ($44 million) and unfavorable changes in working capital ($19 million). Cash used in investing activities of $629 million for the first six months of 2004 increased by $272 million as compared to the same period in 2003 due primarily to increased exploration and development expenditures ($235 million) and unfavorable changes in working capital related to investing activities ($23 million). Changes in Components of Working Capital Associated with Investing Activities included changes in accounts payable associated with the accrual of exploration and development expenditures and changes in inventories which represent materials and equipment used in drilling and related activities. During the first quarter of 2004, EOG completed a sale agreement whereby a portion of an EOG subsidiary's shareholdings in N2000, a Trinidadian company, was sold to a third party energy company for $3 million. The sale left EOG with an equity interest of approximately 23% in N2000 and did not result in any gain or loss. The proceeds were reported as Proceeds from Sales of Assets. Cash used by financing activities was less than $1 million for the first six months of 2004 versus cash used of $155 million for the same period in 2003. Financing activities for 2004 included the net repayment of long-term debt ($23 million) consisting of repayments of the outstanding balances of commercial paper borrowings ($98 million) and a senior unsecured term loan facility ($75 million), offset partially by the notes issuance discussed below ($150 million). Other financing activities included proceeds from the exercise of employee stock options ($43 million) and payments of cash dividends ($18 million). On March 9, 2004, EOG Resources Canada Inc., a wholly owned subsidiary of EOG, issued notes with a total principal amount of US$150 million, an annual interest rate of 4.75% and a maturity date of March 15, 2014, under Rule 144A of the Securities Act of 1933, as amended. The notes are guaranteed by EOG. In conjunction with the offering, EOG entered into a foreign currency swap transaction for the equivalent amount of the notes and related interest, which has in effect converted this indebtedness into CAD$201.3 million with a 5.275% interest rate. Based upon existing economic and market conditions, management believes net operating cash flow and available financing alternatives will be sufficient to fund net investing and other cash requirements of EOG for the foreseeable future. Total Exploration and Development Expenditures The table below presents total exploration and development expenditures for the six-month periods ended June 30, 2004 and 2003 (in millions):
Six Months Ended June 30, 2004 2003 United States $ 446 $ 298 Canada 106 54 United States and Canada 552 352 Trinidad 38 10 United Kingdom 17 11 Other 2 2 Exploration and Development Expenditures 609 375 Asset Retirement Costs 5 3 Deferred Income Tax Benefits on Acquired Properties (17) - Total Exploration and Development Expenditures $ 597 $ 378
Exploration and development expenditures of $609 million for the first half of 2004 were $234 million higher than the prior year period due primarily to increased development and exploratory activities and higher cost structure in the United States and Canada ($200 million), and increased drilling activities in Trinidad ($28 million) and the United Kingdom ($6 million). The 2004 exploration and development expenditures of $609 million included $420 million in development,$182 million in exploration, $4 million in capitalized interest and $3 million in property acquisitions. The 2003 exploration and development expenditures of $375 million included $248 million in development, $105 million in exploration, $18 million in property acquisitions and $4 million in capitalized interest. The level of exploration and development expenditures, including acquisitions, will vary in future periods depending on energy market conditions and other related economic factors. EOG has significant flexibility with respect to financing alternatives and the ability to adjust its exploration and development expenditure budget as circumstances warrant. There are no material continuing commitments associated with expenditure plans. Commodity Derivative Transactions As more fully discussed in Note 12 to the consolidated financial statements included in EOG's Annual Report on Form 10-K for the year ended December 31, 2003, EOG engages in price risk management activities from time to time. These activities are intended to manage EOG's exposure to fluctuations in commodity prices for natural gas and crude oil. EOG utilizes commodity derivative financial instruments, primarily price swaps and collars, as the means to manage this price risk. In addition to these financial transactions, EOG is a party to various physical commodity contracts for the sale of hydrocarbons that cover varying periods of time and have varying pricing provisions. The financial impact of these various physical commodity contracts is included in revenues at the time of settlement, which in turn affects average realized hydrocarbon prices. During the first six months of 2004 and 2003, EOG elected not to designate any of its commodity derivative financial contracts as accounting hedges, and accordingly, accounted for these commodity derivative financial contracts using the mark-to- market accounting method. Presented below is a summary of EOG's remaining 2004 natural gas financial collar contracts and natural gas and crude oil financial price swap contracts at June 30, 2004 with prices expressed in dollars per million British thermal units ($/MMBtu) and in dollars per barrel ($/Bbl), as applicable, and notional volumes in million British thermal units per day (MMBtud) and in barrels per day (Bbld), as applicable. EOG has not entered into any additional natural gas financial collar contracts or natural gas or crude oil financial price swap contracts since EOG filed its Current Report on Form 8-K on August 2, 2004. The total fair value of the natural gas financial collar contracts and natural gas and crude oil financial price swap contracts at June 30, 2004 was a negative $59 million. There are no such contracts for any period after 2004.
Natural Gas Financial Collar Contracts Financial Price Swap Contracts Floor Price Ceiling Price Natural Gas Crude Oil Floor Weighted Weighted Range Weighted Ceiling Weighted Average Average Volume /Floor Average Range Average Volume Price Volume Price Month (MMBtud) ($/MMBtu) ($/MMBtu) ($/MMBtu) ($/MMBtu) (MMBtud) ($/MMBtu) (Bbld) ($/Bbl) Jul 375,000 $4.47 - 4.75 $4.58 $4.93 - 5.19 $5.09 30,000 $4.80 3,000 $27.91 Aug 375,000 4.47 - 4.75 4.58 4.93 - 5.19 5.09 30,000 4.80 2,000 28.11 Sep 375,000 4.47 - 4.75 4.58 4.93 - 5.19 5.09 30,000 4.78 - - Oct 375,000 4.47 - 4.75 4.58 4.93 - 5.19 5.09 30,000 4.80 - - Nov 100,000 6.35 6.35 7.60 - 7.64 7.61 - - - -
Information Regarding Forward-Looking Statements This Quarterly Report on Form 10-Q 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. All statements other than statements of historical facts, including, among others, statements regarding EOG's future financial position, business strategy, budgets, reserve information, projected levels of production, projected costs and plans and objectives of management for future operations, are forward-looking statements. EOG typically uses words such as "expect," "anticipate," "estimate," "strategy," "intend," "plan," "target" and "believe" or the negative of those terms or other variations of them or by comparable terminology to identify its forward-looking statements. In particular, statements, express or implied, concerning future operating results, the ability to replace or increase reserves or to increase production, or the ability to generate income or cash flows are forward-looking statements. 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, foreign currency exchange rates and interest rates; the timing and impact of liquefied natural gas imports and changes in demand or prices for ammonia or methanol; 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; the extent to which EOG can replicate on its other Barnett Shale acreage the results of its most recent Barnett Shale wells; political developments around the world; acts of war and terrorism and responses to these acts; 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. PART 1. FINANCIAL INFORMATION (Concluded) ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK EOG RESOURCES, INC. EOG's exposure to interest rate risk, commodity price risk and foreign currency exchange risk is discussed respectively in the Financing and Outlook sections of the "Management's Discussion and Analysis of Financial Condition and Results of Operations - Capital Resources and Liquidity," on pages 10 through 14 of the Form 8-K filed on February 24, 2004. ITEM 4. CONTROLS AND PROCEDURES EOG RESOURCES, INC. EOG's management, with the participation of EOG's principal executive officer and principal financial officer, evaluated the effectiveness of EOG's disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e) promulgated under the Securities Exchange Act of 1934, as amended (Exchange Act)) as of the end of the quarter ended June 30, 2004. Based on this evaluation, the principal executive officer and principal financial officer have concluded that EOG's disclosure controls and procedures were effective as of the end of the quarter ended June 30, 2004 to ensure that information that is required to be disclosed by EOG in the reports it files or submits under the Exchange Act is recorded, processed, summarized and reported, within the time periods specified in the SEC's rules and forms. There were no changes in EOG's internal control over financial reporting that occurred during the quarter ended June 30, 2004 that have materially affected, or are reasonably likely to materially affect, EOG's internal control over financial reporting. PART II. OTHER INFORMATION EOG RESOURCES, INC. ITEM 1. Legal Proceedings See Part I, Item 1, Note 5 to Consolidated Financial Statements, which is incorporated herein by reference. ITEM 2. Changes in Securities and Use of Proceeds
(c) (a) Total Number of (d) Total (b) Shares Purchased as Maximum Number Number of Average Part of Publicly of Shares that May Yet Shares Price Paid Announced Plans or Be Purchased Under Period Purchased(1) per Share Programs the Plans or Programs(2) April 1, 2004 - April 30, 2004 1,043 $46.59 - 6,386,200 May 1, 2004 - May 31, 2004 65,219 52.19 - 6,386,200 June 1, 2004 - June 30, 2004 46 53.73 - 6,386,200 Total 66,308 $51.97 - (1) Includes 52,274 shares that were returned to EOG in payment of the exercise price of employee stock options and 14,034 shares that were returned to EOG to satisfy tax withholding obligations that arose upon the exercise of employee stock options or the vesting of restricted stock or units. (2) In September 2001, EOG announced that its Board of Directors authorized the repurchase of up to 10,000,000 shares of EOG's common stock.
ITEM 4. Submission of Matters to a Vote of Security Holders The Annual Meeting of Shareholders of EOG Resources, Inc. was held on May 4, 2004, in Houston, Texas, for the purpose of electing a board of directors, ratifying the appointment of auditors and approving EOG's Amended and Restated 1992 Stock Plan. Proxies for the meeting were solicited pursuant to Section 14(a) of the Securities Exchange Act of 1934, and there was no solicitation in opposition to management's solicitations. (a) Each of the directors nominated by the Board and listed in the proxy statement was elected with votes as follows: Shares Shares Nominee For Withheld George A. Alcorn 102,580,412 2,817,641 Charles R. Crisp 102,633,144 2,764,909 Mark G. Papa 103,091,689 2,306,364 Edmund P. Segner, III 102,868,915 2,529,138 Donald F. Textor 101,979,815 3,418,238 Frank G. Wisner 102,592,185 2,805,868 (b) The appointment of Deloitte & Touche LLP, independent public accountants, as auditors for the year ending December 31, 2004 was ratified by the following vote: 103,387,415 shares for; 1,359,286 shares against; and 535,373 shares abstaining. (c) EOG's Amended and Restated 1992 Stock Plan was approved by the following vote: 85,375,150 shares for; 10,155,324 shares against; and 703,041 shares abstaining. PART II. OTHER INFORMATION (Concluded) EOG RESOURCES, INC. ITEM 5. Other Information On July 2, 2004, EOG announced that Mr. W. D. (Bill) Stevens and Mr. H. Leighton Steward had been elected to its Board of Directors. ITEM 6. Exhibits and Current Reports on Form 8-K (a) Exhibits Exhibit 31.1 - Section 302 Certification of Periodic Report of Chief Executive Officer. Exhibit 31.2 - Section 302 Certification of Periodic Report of Principal Financial Officer. Exhibit 32.1 - Section 906 Certification of Periodic Report of Chief Executive Officer. Exhibit 32.2 - Section 906 Certification of Periodic Report of Principal Financial Officer. (b) Current Reports on Form 8-K During the second quarter of 2004, EOG furnished the following Current Reports on Form 8-K: - On April 5, 2004, to report anticipated financial results of the price risk management activities for the first quarter of 2004 and provide updated information on the remaining 2004 natural gas financial collar contracts and natural gas and crude oil financial price swap contracts in Item 9 - Regulation FD Disclosure. - On April 30, 2004, to provide estimates for the second quarter and full year 2004 and to provide updated information on the remaining 2004 natural gas financial collar contracts and natural gas and crude oil financial price swap contracts in Item 9 - Regulation FD Disclosure. - On May 3, 2004, to furnish the press release issued on May 2, 2004 for the first quarter 2004 financial and operational results in Item 7 - Financial Statements and Exhibits and Item 12 - Results of Operations and Financial Condition. SIGNATURES 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. (Registrant) Date: August 3, 2004 By: /s/ TIMOTHY K. DRIGGERS Timothy K. Driggers Vice President and Chief Accounting Officer (Principal Accounting Officer) EXHIBIT INDEX Exhibit Number Description *31.1 -- Section 302 Certification of Periodic Report of Chief Executive Officer. *31.2 -- Section 302 Certification of Periodic Report of Principal Financial Officer. *32.1 -- Section 906 Certification of Periodic Report of Chief Executive Officer. *32.2 -- Section 906 Certification of Periodic Report of Principal Financial Officer. *Exhibits filed herewith
EX-31 2 ex31_1.txt SECTION 302 CERTIFICATION OF CHIEF EXECUTIVE OFFICER Exhibit 31.1 CERTIFICATIONS I, Mark G. Papa, the Principal Executive Officer of EOG Resources, Inc., a Delaware corporation, certify that: 1. I have reviewed this quarterly report on Form 10-Q of EOG Resources, Inc.; 2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report; 3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report; 4. The registrant's other certifying officers and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) for the registrant and have: a) designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared; b) [Paragraph omitted in accordance with SEC transition instructions contained in SEC Release 34-47986] c) evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and d) disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting. 5. The registrant's other certifying officers and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of registrant's board of directors (or persons performing the equivalent functions): a) all significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and b) any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting. Date: August 3, 2004 /s/ MARK G. PAPA Mark G. Papa Chairman of the Board and Chief Executive Officer (Principal Executive Officer) EX-31 3 ex31_2.txt SECTION 302 CERTIFICATION OF PRINCIPAL FINANCIAL OFFICER Exhibit 31.2 CERTIFICATIONS I, Edmund P. Segner, III, the Principal Financial Officer of EOG Resources, Inc., a Delaware corporation, certify that: 1. I have reviewed this quarterly report on Form 10-Q of EOG Resources, Inc.; 2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report; 3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report; 4. The registrant's other certifying officers and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) for the registrant and have: a) designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared; b) [Paragraph omitted in accordance with SEC transition instructions contained in SEC Release 34-47986] c) evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and d) disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting. 5. The registrant's other certifying officers and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of registrant's board of directors (or persons performing the equivalent functions): a) all significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and b) any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting. Date: August 3, 2004 /s/ EDMUND P. SEGNER, III Edmund P. Segner, III President and Chief of Staff (Principal Financial Officer) EX-32 4 ex32_1.txt SECTION 906 CERTIFICATION OF CHIEF EXECUTIVE OFFICER Exhibit 32.1 CERTIFICATION OF PERIODIC REPORT I, Mark G. Papa, Chairman of the Board and Chief Executive Officer of EOG Resources, Inc., a Delaware Corporation (the "Company"), certify, pursuant to Section 906 of the Sarbanes- Oxley Act of 2002, 18 U.S.C. Section 1350, that: (1) the Quarterly Report on Form 10-Q of the Company for the quarterly period ended June 30, 2004 (the "Report") fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934 (15 U.S.C. 78m or 78o(d)); and (2) the information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company. A signed original of this written statement required by Section 906 has been provided to the Company and will be retained by the Company and furnished to the Securities and Exchange Commission or its staff upon request. Dated: August 3, 2004 /s/ MARK G. PAPA Mark G. Papa Chairman of the Board and Chief Executive Officer EX-32 5 ex32_2.txt SECTION 906 CERTIFICATION OF PRINCIPAL FINANCIAL OFFICER Exhibit 32.2 CERTIFICATION OF PERIODIC REPORT I, Edmund P. Segner, III, President and Chief of Staff, and Principal Financial Officer of EOG Resources, Inc., a Delaware Corporation (the "Company"), certify, pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, 18 U.S.C. Section 1350, that: (1) the Quarterly Report on Form 10-Q of the Company for the quarterly period ended June 30, 2004 (the "Report") fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934 (15 U.S.C. 78m or 78o(d)); and (2) the information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company. A signed original of this written statement required by Section 906 has been provided to the Company and will be retained by the Company and furnished to the Securities and Exchange Commission or its staff upon request. Dated: August 3, 2004 /s/ EDMUND P. SEGNER, III Edmund P. 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