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, 2003 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 24, 2003. Title of each class Number of shares Common Stock, $.01 par value 114,885,338 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, 2003 and 2002 And Six Months Ended June 30, 2003 and 2002 3 Consolidated Balance Sheets - June 30, 2003 and December 31, 2002 4 Consolidated Statements of Cash Flows - Six Months Ended June 30, 2003 and 2002 5 Notes to Consolidated Financial Statements 6 ITEM 2. Management's Discussion and Analysis of Financial Condition and Results of Operations 11 ITEM 4. Controls and Procedures 20 PART II.OTHER INFORMATION ITEM 1. Legal Proceedings 21 ITEM 4. Submission of Matters to a Vote of Security Holders 21 ITEM 6. Exhibits and Reports on Form 8-K 22 SIGNATURES 23 EXHIBIT INDEX 24 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, 2003 2002 2003 2002 NET OPERATING REVENUES Natural Gas $377,643 $231,272 $811,734 $407,856 Crude Oil, Condensate and Natural Gas Liquids 61,471 56,635 136,979 103,410 Gains (Losses) on Mark-to-market Commodity Derivative Contracts (15,753) 693 (60,974) (33,602) Other, Net 1,393 1,563 1,684 (938) TOTAL 424,754 290,163 889,423 476,726 OPERATING EXPENSES Lease and Well 53,620 43,638 101,959 84,229 Exploration Costs 22,139 15,754 39,597 28,690 Dry Hole Costs 3,436 12,836 10,056 23,242 Impairments 25,475 10,683 37,431 22,746 Depreciation, Depletion and Amortization 106,587 97,956 210,140 192,416 General and Administrative 24,934 21,988 45,355 42,701 Taxes Other Than Income 11,695 18,008 41,888 34,048 TOTAL 247,886 220,863 486,426 428,072 OPERATING INCOME 176,868 69,300 402,997 48,654 OTHER INCOME (EXPENSE), NET 2,680 437 2,832 (2,726) INCOME BEFORE INTEREST EXPENSE AND INCOME TAXES 179,548 69,737 405,829 45,928 INTEREST EXPENSE, NET 13,807 14,182 29,125 26,233 INCOME BEFORE INCOME TAXES 165,741 55,555 376,704 19,695 INCOME TAX PROVISION 56,950 17,447 131,357 5,828 NET INCOME BEFORE CUMULATIVE EFFECT OF CHANGE IN ACCOUNTING PRINCIPLE 108,791 38,108 245,347 13,867 CUMULATIVE EFFECT OF CHANGE IN ACCOUNTING PRINCIPLE, NET OF TAX - - (7,131) - NET INCOME 108,791 38,108 238,216 13,867 PREFERRED STOCK DIVIDENDS 2,758 2,758 5,516 5,516 NET INCOME AVAILABLE TO COMMON $106,033 $ 35,350 $232,700 $ 8,351 NET INCOME PER SHARE AVAILABLE TO COMMON Basic Net Income Available to Common Before Cumulative Effect of Change in Accounting Principle $ 0.93 $ 0.31 $ 2.09 $ 0.07 Cumulative Effect of Change in Accounting Principle, net of tax - - (0.06) - Net Income Available to Common $ 0.93 $ 0.31 $ 2.03 $ 0.07 Diluted Net Income Available to Common Before Cumulative Effect of Change in Accounting Principle $ 0.91 $ 0.30 $ 2.06 $ 0.07 Cumulative Effect of Change in Accounting Principle, net of tax - - (0.06) - Net Income Available to Common $ 0.91 $ 0.30 $ 2.00 $ 0.07 AVERAGE NUMBER OF COMMON SHARES Basic 114,382 115,737 114,430 115,553 Diluted 116,131 117,689 116,212 117,397 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, 2003 2002 (Unaudited) ASSETS CURRENT ASSETS Cash and Cash Equivalents $ 150,967 $ 9,848 Accounts Receivable, Net 303,804 259,308 Inventories 18,972 18,928 Other 79,038 106,708 TOTAL 552,781 394,792 OIL AND GAS PROPERTIES (SUCCESSFUL EFFORTS METHOD) 7,269,638 6,750,095 Less: Accumulated Depreciation, Depletion and Amortization (3,674,781) (3,428,547) Net Oil and Gas Properties 3,594,857 3,321,548 OTHER ASSETS 92,703 97,666 TOTAL ASSETS $ 4,240,341 $ 3,814,006 LIABILITIES AND SHAREHOLDERS' EQUITY CURRENT LIABILITIES Accounts Payable $ 226,408 $ 201,931 Accrued Taxes Payable 29,781 23,170 Dividends Payable 6,151 5,007 Liabilities from Price Risk Management Activities 27,700 5,939 Other 33,080 40,304 TOTAL 323,120 276,351 LONG-TERM DEBT 1,010,822 1,145,132 OTHER LIABILITIES 158,064 59,180 DEFERRED INCOME TAXES 766,531 660,948 SHAREHOLDERS' EQUITY Preferred Stock, $.01 Par, 10,000,000 Shares Authorized: Series B, 100,000 Shares Issued, Cumulative, $100,000,000 Liquidation Preference 98,471 98,352 Series D, 500 Shares Issued, Cumulative, $50,000,000 Liquidation Preference 49,736 49,647 Common Stock, $.01 Par, 320,000,000 Shares Authorized and 124,730,000 Shares Issued 201,247 201,247 Additional Paid in Capital 29 - Unearned Compensation (17,227) (15,033) Accumulated Other Comprehensive Gain (Loss) 37,546 (49,877) Retained Earnings 1,946,331 1,723,948 Common Stock Held in Treasury, 9,853,722 shares at June 30, 2003 and 10,009,740 shares at December 31, 2002 (334,329) (335,889) TOTAL SHAREHOLDERS' EQUITY 1,981,804 1,672,395 TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY $ 4,240,341 $ 3,814,006 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, 2003 2002 CASH FLOWS FROM OPERATING ACTIVITIES Reconciliation of Net Income to Net Operating Cash Inflows: Net Income $ 238,216 $ 13,867 Items Not Requiring Cash Depreciation, Depletion and Amortization 210,140 192,416 Impairments 37,431 22,746 Deferred Income Taxes 79,975 3,724 Cumulative Effect of Change in Accounting Principle 7,131 - Other, Net 3,965 6,386 Exploration Costs 39,597 28,690 Dry Hole Costs 10,056 23,242 Mark-to-market Commodity Derivative Contracts Total Losses 60,974 33,602 Realized Losses (39,089) (8,828) Tax Benefits from Stock Options Exercised 4,802 2,403 Other, Net 3,499 1,014 Changes in Components of Working Capital and Other Liabilities Accounts Receivable (44,420) (9,722) Inventories (44) 1,813 Accounts Payable 24,353 (50,786) Accrued Taxes Payable 16,371 (3,591) Other Liabilities (1,151) (1,455) Other, Net 8,337 (25,927) Changes in Components of Working Capital Associated with Investing and Financing Activities (6,931) 44,497 NET OPERATING CASH INFLOWS 653,212 274,091 INVESTING CASH FLOWS Additions to Oil and Gas Properties (325,046) (351,761) Exploration Costs (39,597) (28,690) Dry Hole Costs (10,056) (23,242) Proceeds from Sales of Assets 9,750 4,620 Changes in Components of Working Capital Associated with Investing Activities 6,879 (45,050) Other, Net 1,279 212 NET INVESTING CASH OUTFLOWS (356,791) (443,911) FINANCING CASH FLOWS Long-Term Debt Borrowings (Repayments) (134,310) 179,874 Dividends Paid (14,480) (14,577) Treasury Stock Purchased (21,295) - Proceeds from Sales of Treasury Stock 14,730 13,073 Other, Net 53 (1,856) NET FINANCING CASH INFLOWS (OUTFLOWS) (155,302) 176,514 INCREASE IN CASH AND CASH EQUIVALENTS 141,119 6,694 CASH AND CASH EQUIVALENTS AT BEGINNING OF PERIOD 9,848 2,512 CASH AND CASH EQUIVALENTS AT END OF PERIOD $ 150,967 $ 9,206 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. and subsidiaries (EOG) included herein have been prepared by management without audit pursuant to the rules and regulations of the Securities and Exchange Commission. 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, 2002 ("EOG's 2002 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 11 to the consolidated financial statements included in EOG's 2002 Annual Report, EOG engages in price risk management activities from time to time. Derivative financial instruments (primarily price swaps and collars) are utilized selectively to hedge the impact of market fluctuations on natural gas and crude oil prices. During the first half of 2003 and 2002, EOG elected not to designate any of its price risk management activities as accounting hedges, and accordingly, accounted for them using the mark-to-market accounting method. In June 2001, the Financial Accounting Standards Board ("FASB") issued Statement of Financial Accounting Standards ("SFAS") No. 143 - "Accounting for Asset Retirement Obligations" effective for fiscal years beginning after June 15, 2002. As more fully discussed in Note 1 to the consolidated financial statements included in EOG's 2002 Annual Report, SFAS No. 143 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. EOG adopted the statement on January 1, 2003. The adoption of SFAS No. 143 did not have a material effect on the financial condition or results of operations of EOG (see Note 6). In December 2002, the 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 8). Subsequently, at the April 22, 2003 FASB meeting, the FASB decided to require all companies to expense the value of employee stock options. Companies will be required to measure the cost according to the fair value of the options under a method yet to be determined. EOG continues to monitor the developments in this area as details of the implementation of the decision emerge. PART I. FINANCIAL INFORMATION (Continued) ITEM 1. FINANCIAL STATEMENTS (Continued) EOG RESOURCES, INC. NOTES TO CONSOLIDATED FINANCIAL STATEMENTS In April 2003, the FASB issued SFAS No. 149 - "Amendment of Statement 133 on Derivative Instruments and Hedging Activities." This statement amends and clarifies SFAS No. 133 as a result of various implementation issues and does not impact the accounting treatment of EOG's derivative financial instruments. In May 2003, the FASB issued SFAS No. 150 - "Accounting for Certain Financial Instruments with Characteristics of both Liabilities and Equity." Currently, EOG does not have any financial instruments in place which fall under the scope of this statement. 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, 2003 and 2002 (in thousands, except per share amounts):
Three Months Ended Six Months Ended June 30, June 30, 2003 2002 2003 2002 Numerator for Basic and Diluted Earnings Per Share - Net Income Available to Common $106,033 $ 35,350 $232,700 $ 8,351 Denominator for Basic Earnings Per Share - Weighted Average Shares 114,382 115,737 114,430 115,553 Potential Dilutive Common Shares - Stock Options 1,509 1,719 1,531 1,609 Restricted Stock and Units 240 233 251 235 Denominator for Diluted Earnings Per Share - Adjusted Weighted Average Shares 116,131 117,689 116,212 117,397 Net Income Per Share of Common Stock Basic $ 0.93 $ 0.31 $ 2.03 $ 0.07 Diluted $ 0.91 $ 0.30 $ 2.00 $ 0.07
3. The following table presents the components of EOG's comprehensive income for the three-month and six-month periods ended June 30, 2003 and 2002:
Three Months Ended Six Months Ended June 30, June 30, 2003 2002 2003 2002 (In Thousands) Net Income $108,791 $ 38,108 $238,216 $ 13,867 Other Comprehensive Income Foreign Currency Translation Adjustment 48,167 23,413 87,423 23,519 Available-for-Sale Security Transactions - - - 926 Comprehensive Income $156,958 $ 61,521 $325,639 $ 38,312
PART I. FINANCIAL INFORMATION (Continued) ITEM 1. FINANCIAL STATEMENTS (Continued) EOG RESOURCES, INC. NOTES TO CONSOLIDATED FINANCIAL STATEMENTS 4. Selected financial information about operating segments is reported below for the three-month and six-month periods ended June 30, 2003 and 2002:
Three Months Ended Six Months Ended June 30, June 30, 2003 2002 2003 2002 (In Thousands) NET OPERATING REVENUES United States $328,517 $227,944 $687,022 $368,813 Canada 72,916 45,031 153,605 75,438 Trinidad 23,304 17,175 48,768 32,452 Other 17 13 28 23 TOTAL $424,754 $290,163 $889,423 $476,726 OPERATING INCOME (LOSS) United States $126,301 $ 52,564 $288,418 $ 21,785 Canada 40,127 8,470 91,517 9,746 Trinidad 10,736 10,613 27,707 19,490 Other (296) (2,347) (4,645) (2,367) TOTAL 176,868 69,300 402,997 48,654 RECONCILING ITEMS Other Income (Expense), Net 2,680 437 2,832 (2,726) Interest Expense, Net 13,807 14,182 29,125 26,233 INCOME BEFORE INCOME TAXES $165,741 $ 55,555 $376,704 $ 19,695
5. EOG and numerous other companies in the natural gas industry are named as defendants in various lawsuits alleging violations of the Civil False Claims Act. These lawsuits have been consolidated for pre-trial proceedings in the United States District Court for the District of Wyoming. The plaintiffs contend that defendants have underpaid royalties on natural gas and natural gas liquids produced on federal and Indian lands through the use of below-market prices, improper deductions, improper measurement techniques and transactions with affiliated companies. Plaintiffs allege that the royalties paid by defendants were lower than the royalties required to be paid under federal regulations and that the forms filed by defendants with the Minerals Management Service reporting these royalty payments were false, thereby violating the Civil False Claims Act. Based on EOG's present understanding of these cases, EOG believes that it has substantial defenses to these claims and intends to vigorously assert these defenses. However, if EOG is found to have violated the Civil False Claims Act, EOG could be subject to a variety of sanctions, including treble damages and substantial monetary fines. There are various other suits and claims against EOG that have arisen in the ordinary course of business. However, management does not believe these suits and claims will individually or in the aggregate have a material adverse effect on the financial condition or results of operations of EOG. 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 materially adverse effect on the financial condition or results of operations of EOG. PART I. FINANCIAL INFORMATION (Continued) ITEM 1. FINANCIAL STATEMENTS (Continued) EOG RESOURCES, INC. NOTES TO CONSOLIDATED FINANCIAL STATEMENTS 6. EOG adopted SFAS No. 143 - "Accounting for Asset Retirement Obligations" on January 1, 2003. The impact of adopting the statement resulted in an after-tax loss of $7.1 million, which was reported in the first quarter of 2003 as cumulative effect of change in accounting principle. 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, 2003 and June 30, 2003 (in thousands):
Asset Retirement Obligations Short-Term Long-Term Total Balance at December 31, 2002 $ - $ - $ - Carrying Amount at Adoption 6,384 92,097 98,481 Liabilities Incurred - 1,036 1,036 Liabilities Settled (329) (82) (411) Accretion 31 1,081 1,112 Foreign Currency Translation 43 697 740 Balance at March 31, 2003 6,129 94,829 100,958 Liabilities Incurred 7 1,985 1,992 Liabilities Settled (250) (393) (643) Accretion 31 1,172 1,203 Foreign Currency Translation 45 719 764 Balance at June 30, 2003 $ 5,962 $98,312 $104,274
Pro forma net income and earnings per share are not presented for the three or six-month periods ended June 30, 2002 because the pro forma application of SFAS No. 143 to the prior period would not result in pro forma net income and earnings per share materially different from the actual amounts reported for the period in the accompanying Consolidated Statements of Income. 7. EOG, through certain wholly-owned subsidiaries, owns equity interests in two Trinidadian companies: Caribbean Nitrogen Company Limited ("CNCL") and Nitrogen (2000) Unlimited ("N2000"). During the first quarter of 2003, EOG completed separate share purchase agreements whereby a portion of the EOG subsidiaries' shareholdings in CNCL and N2000 was sold to a third party energy company. The sale left EOG with equity interests of approximately 12% in CNCL and 27% in N2000 and did not result in any gain or loss. 8. EOG has various stock plans ("the 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 as of 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. PART I. FINANCIAL INFORMATION (Continued) ITEM 1. FINANCIAL STATEMENTS (Concluded) EOG RESOURCES, INC. NOTES TO CONSOLIDATED FINANCIAL STATEMENTS EOG's pro forma net income and net income per share of common stock for the three-month and six-month periods ended June 30, 2003 and 2002, had compensation costs 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 thousands except per share data):
Three Months Ended Six Months Ended June 30, June 30, 2003 2002 2003 2002 Net Income Available to Common - As Reported $106,033 $ 35,350 $232,700 $ 8,351 Deduct: Total Stock-Based Employee Compensation Expense (2,354) (2,090) (5,647) (6,255) Net Income Available to Common - Pro Forma $103,679 $ 33,260 $227,053 $ 2,096 Net Income per Share Available to Common Basic - As Reported $ 0.93 $ 0.31 $ 2.03 $ 0.07 Basic - Pro Forma $ 0.91 $ 0.29 $ 1.98 $ 0.02 Diluted - As Reported $ 0.91 $ 0.30 $ 2.00 $ 0.07 Diluted - Pro Forma $ 0.89 $ 0.28 $ 1.95 $ 0.02
The effects of applying SFAS No. 123, as amended, should not be interpreted as being indicative of future effects. The statement 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 both three-month periods ended June 30, 2003 and 2002 was $1.3 million. Related compensation expense for the six-month periods ended June 30, 2003 and 2002 was $2.6 million and $2.4 million, respectively. 9. On July 23, 2003, EOG entered into a new three-year credit facility with domestic and foreign lenders which provides for $600 million in long-term committed credit, and concurrently cancelled the existing $300 million 364-day credit facility and $300 million five-year credit facility scheduled to expire in July 2003 and July 2004, respectively. Advances under the new agreement bear interest, at the option of EOG, based upon a base rate or a Eurodollar rate. The new credit facility also provides for the allocation, at the option of EOG, of up to $75 million of the $600 million to its Canadian subsidiary. Advances to the Canadian subsidiary, should they occur, would be guaranteed by EOG and would bear interest at the option of the Canadian subsidiary based upon a Canadian prime rate or a Canadian banker's acceptance rate. EOG also has the option to issue up to $100 million in letters of credit as part of this new credit facility. PART I. FINANCIAL INFORMATION (Continued) ITEM 2. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS EOG RESOURCES, INC. The following review of operations for the three-month periods ended June 30, 2003 and 2002 should be read in conjunction with the consolidated financial statements of EOG Resources, Inc. and subsidiaries (EOG) and Notes thereto. Results of Operations Three Months Ended June 30, 2003 vs. Three Months Ended June 30, 2002 Net Operating Revenues. Wellhead volume and price statistics for the specified quarters were as follows:
Three Months Ended June 30, 2003 2002 Natural Gas Volumes (MMcf per day)(1) United States 636 628 Canada 153 159 North America 789 787 Trinidad 148 111 TOTAL 937 898 Average Natural Gas Prices ($/Mcf)(2) United States $5.06 $3.05 Canada 4.77 2.76 North America Composite 5.00 2.99 Trinidad 1.32 1.27 COMPOSITE 4.42 2.77 Crude Oil/Condensate Volumes (MBbl per day)(1) United States 17.3 19.2 Canada 2.3 2.0 North America 19.6 21.2 Trinidad 2.3 1.9 TOTAL 21.9 23.1 Average Crude Oil/Condensate Prices ($/Bbl)(2) United States $28.18 $24.86 Canada 27.00 23.93 North America Composite 28.04 24.77 Trinidad 26.31 24.46 COMPOSITE 27.86 24.74 Natural Gas Liquids Volumes (MBbl per day)(1) United States 3.0 2.9 Canada 0.4 0.7 TOTAL 3.4 3.6 Average Natural Gas Liquids Prices ($/Bbl)(2) United States $19.63 $14.86 Canada 14.15 10.53 COMPOSITE 19.00 13.95 Natural Gas Equivalent Volumes (MMcfe per day)(3) United States 757 760 Canada 170 175 North America 927 935 Trinidad 162 124 TOTAL 1,089 1,059 Total Bcfe(3)Deliveries 99 96 (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.
PART I. FINANCIAL INFORMATION (Continued) ITEM 2. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS - (Continued) EOG RESOURCES, INC. During the second quarter of 2003, net operating revenues increased $135 million to $425 million. Total wellhead revenues of $439 million increased by $155 million, or 55%, as compared to a year ago. Wellhead natural gas revenues for the second quarter of 2003 increased approximately $150 million, or 66%, due to an increase in average wellhead natural gas prices and an increase in natural gas deliveries. The average wellhead price for natural gas increased 60% to $4.42 per Mcf for the second quarter of 2003 from $2.77 per Mcf for the same quarter of 2002. Natural gas deliveries increased to 937 MMcf per day for the second quarter of 2003 from 898 MMcf per day a year ago. The increase in natural gas deliveries was primarily due to production from the U(a) Block in Trinidad, where production did not commence until May 2002, and to increased production in the Oklahoma City, Corpus Christi and Midland Divisions. Wellhead crude oil and condensate revenues for the second quarter of 2003 increased approximately $4 million, or 7%, as compared to the prior year period, primarily due to an increase in the average wellhead crude oil and condensate prices, partially offset by lower crude oil and condensate deliveries. The average wellhead price for crude oil and condensate increased 13% to $27.86 per barrel from $24.74 per barrel for the same quarter of 2002. Crude oil and condensate deliveries decreased 5% to 21.9 MBbl per day for the second quarter of 2003 from 23.1 MBbl per day a year ago. The decrease in volumes was primarily due to a natural decline in crude oil and condensate production in the Denver, Tyler and Oklahoma City Divisions, partially offset by increased production in the Midland Division, Trinidad and Canada. During the second quarter of 2003, EOG recognized a loss on mark- to-market commodity derivative contracts of $15.8 million compared to a gain of $0.7 million for the prior year period. During the same period, net cash outflows from mark-to-market commodity derivative contracts were $11.2 million compared to net cash outflows of $19.8 million for the comparable period in 2002. Operating Expenses. For the second quarter of 2003, operating expenses of $248 million were approximately $27 million higher than the second quarter of 2002. Impairments increased $15 million to $25 million in the second quarter of 2003 compared to a year ago due to higher amortization of unproved leases and impairments to the carrying value of certain long-lived assets as a result of future cash flow analysis, primarily in the Pittsburgh Division. For the three-month periods ended June 30, 2003 and 2002, total impairments under SFAS No. 144 - "Accounting for the Impairment or Disposal of Long-Lived Assets" were $8 million and $3 million, respectively, and were included on the "Impairments" line of the Consolidated Statements of Income. Lease and well expenses of $54 million were $10 million higher than the comparable period a year ago due primarily to continually expanding operations, changes in the Canadian exchange rate, increased expenditures for workovers and higher production costs from certain properties in Canada, and the Corpus Christi, Denver, Midland and Tyler Divisions. Dry hole costs of $3 million were $9 million lower than the comparable period a year ago. PART I. FINANCIAL INFORMATION (Continued) ITEM 2. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS - (Continued) EOG RESOURCES, INC. Depreciation, depletion and amortization ("DD&A") expenses of $107 million increased $9 million from the prior year period due primarily to higher DD&A rates in Canada and the Offshore, Corpus Christi and Oklahoma City Divisions, and to increased production volumes as previously described. Second quarter 2003 DD&A expenses were impacted by changes in the Canadian exchange rate and also included $1 million of accretion expense related to SFAS No. 143 - "Accounting for Asset Retirement Obligations." Exploration costs of $22 million were $6 million higher than a year ago due primarily to a 3-D seismic project in Trinidad. Taxes other than income were $6 million lower than the prior year period primarily due to a $17 million credit from severance tax adjustments resulting from the qualification of additional wells for a Texas high cost gas severance tax exemption, partially offset by the impact of increased wellhead revenue as previously discussed. General and administrative ("G&A") expenses of $25 million were $3 million higher than a year ago due primarily to increased insurance expense and expanded operations. Per-Unit Costs. The following table presents the costs per Mcfe for the three-month periods ended June 30, 2003 and 2002:
Three Months Ended June 30, 2003 2002 Lease and Well $0.54 $0.45 DD&A 1.08 1.02 G&A 0.25 0.23 Taxes Other than Income 0.12 0.18 Interest Expense 0.14 0.15 Total Per-Unit Costs $2.13 $2.03
The higher per-unit rates of lease and well and G&A, and the lower per-unit rates of taxes other than income for the three-month period ended June 30, 2003 compared to the same period in 2002 were due primarily to the reasons delineated in the above discussion. The higher per-unit DD&A rate for the three-month period ended June 30, 2003 compared to the same period in 2002 was due primarily to increased production from higher cost properties in Canada and the Corpus Christi and Oklahoma City Divisions. The rate was also affected by changes in the Canadian exchange rate and the reduced reserve estimate for a certain offshore field. SFAS No. 143 accretion expense increased the DD&A rate by $0.01 per Mcfe in the second quarter of 2003. Income Tax Provision. Income tax provision for the second quarter of 2003 was $57 million compared to $17 million for the comparable period of 2002, due to increases of both the pre-tax income and the effective tax rate. The increase in the effective tax rate for the second quarter of 2003 to 34% from 31% for the same period of 2002 was due primarily to the expiration of the Section 29 Credit provision in the Internal Revenue Code as of December 31, 2002. PART I. FINANCIAL INFORMATION (Continued) ITEM 2. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS - (Continued) EOG RESOURCES, INC. Results of Operations Six Months Ended June 30, 2003 vs. Six Months Ended June 30, 2002 Net Operating Revenues. Wellhead volume and price statistics for the specified periods were as follows:
Six Months Ended June 30, 2003 2002 Natural Gas Volumes (MMcf per day) United States 639 631 Canada 155 152 North America 794 783 Trinidad 152 110 TOTAL 946 893 Average Natural Gas Prices ($/Mcf) United States $5.49 $2.65 Canada 4.97 2.54 North America Composite 5.39 2.63 Trinidad 1.32 1.27 COMPOSITE 4.74 2.46 Crude Oil/Condensate Volumes (MBbl per day) United States 17.8 19.6 Canada 2.2 1.9 North America 20.0 21.5 Trinidad 2.4 1.9 TOTAL 22.4 23.4 Average Crude Oil/Condensate Prices ($/Bbl) United States $30.63 $22.42 Canada 29.26 21.66 North America Composite 30.48 22.36 Trinidad 29.82 21.11 COMPOSITE 30.41 22.26 Natural Gas Liquids Volumes (MBbl per day) United States 3.1 3.4 Canada 0.5 0.7 TOTAL 3.6 4.1 Average Natural Gas Liquids Prices ($/Bbl) United States $21.46 $12.83 Canada 19.22 9.51 COMPOSITE 21.13 12.21 Natural Gas Equivalent Volumes (MMcfe per day) United States 764 769 Canada 172 168 North America 936 937 Trinidad 166 121 TOTAL 1,102 1,058 Total Bcfe Deliveries 199 192
PART I. FINANCIAL INFORMATION (Continued) ITEM 2. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS - (Continued) EOG RESOURCES, INC. Wellhead revenues increased 89% to $948 million in the first half of 2003 from $501 million in the first half of 2002. Wellhead natural gas revenues increased approximately $413 million, or 104%, due to increases in average wellhead natural gas prices and natural gas deliveries. The average wellhead price for natural gas increased 93% to $4.74 per Mcf for the first half of 2003 from $2.46 per Mcf for the same period a year ago. Natural gas deliveries increased to 946 MMcf per day for the first half of 2003 from 893 MMcf per day a year ago. The increase in natural gas deliveries was primarily due to the production from the U(a) Block in Trinidad, where production did not commence until May 2002, and to increased production in the Oklahoma City and Corpus Christi Divisions. Wellhead crude oil and condensate revenues for the first half of 2003 increased approximately $29 million, or 31%, as compared to the prior year period, primarily due to an increase in the average wellhead crude oil and condensate prices, partially offset by lower crude oil and condensate deliveries. The average wellhead price for crude oil and condensate increased 37% to $30.41 per barrel compared to $22.26 per barrel for the comparable period a year ago. Crude oil and condensate deliveries decreased 4% to 22.4 MBbl per day for the first half of 2003 from 23.4 MBbl per day a year ago. The decrease in volumes was primarily due to a natural decline in crude oil and condensate production in the Tyler, Denver and Oklahoma City Divisions, partially offset by increased production in Canada, the Corpus Christi Division and Trinidad, where production from the U(a) Block did not commence until May 2002. Natural gas liquids revenues were approximately $5 million higher than a year ago primarily due to a 73% increase in prices, partially offset by a 12% decrease in deliveries. During the first six months of 2003, EOG recognized a loss on mark- to-market commodity derivative contracts of $61.0 million compared to a loss of $33.6 million for the prior year period. During the same period, net cash outflows from mark-to-market commodity derivative contracts were $39.1 million compared to net cash outflows of $8.8 million for the comparable period in 2002. Operating Expenses. For the first six months of 2003, operating expenses of $486 million were approximately $58 million higher than the first six months of 2002. Lease and well expenses of $102 million were $18 million higher than the comparable period a year ago due primarily to continually expanding operations, changes in the Canadian exchange rate, increased expenditures for workovers and higher production costs from certain properties in Canada, and the Corpus Christi, Denver, Tyler and Midland Divisions. DD&A expenses of $210 million increased $18 million from the prior year period due primarily to higher DD&A rates in Canada, and the Corpus Christi and Offshore Divisions, and to increased production volumes as discussed above. DD&A expenses for the first six months of 2003 were impacted by changes in the Canadian exchange rate and also included $2 million of accretion expense related to SFAS No. 143 - "Accounting for Asset Retirement Obligations." PART I. FINANCIAL INFORMATION (Continued) ITEM 2. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS - (Continued) EOG RESOURCES, INC. Impairments increased $15 million to $37 million in the first six months of 2003 compared to a year ago due to higher amortization of unproved leases and impairments to the carrying value of certain long-lived assets as a result of future cash flow analysis, primarily in the Pittsburgh Division. For the six-month periods ended June 30, 2003 and 2002, total impairments under SFAS No. 144 - "Accounting for the Impairment or Disposal of Long-Lived Assets" were $8 million and $5 million, respectively, and were included on the "Impairments" line of the Consolidated Statements of Income. Dry hole costs of $10 million were $13 million lower than the comparable period a year ago. Exploration costs of $40 million were $11 million higher than a year ago due primarily to a 3-D seismic project in Trinidad, increased geological and geoscience expenditures in the United States and increased investment in technical staff across EOG. Taxes other than income were $8 million higher than the comparable prior year period due to the impact of increased wellhead revenue, partially offset by an $18 million credit from severance tax adjustments resulting from the qualification of additional wells for a Texas high cost gas severance tax exemption. G&A expenses of $45 million were $3 million higher than a year ago due primarily to increased insurance expense and expanded operations. Interest Expense, Net. For the first half of 2003, interest expense increased approximately $3 million compared to the first half of 2002 due to a slightly higher average debt balance and a $1 million interest charge related to a completed Texas sales tax audit. Per-Unit Costs. The following table presents the costs per Mcfe for the six-month periods ended June 30, 2003 and 2002:
Six Months Ended June 30, 2003 2002 Lease and Well $0.51 $0.44 DD&A 1.05 1.00 G&A 0.23 0.22 Taxes Other than Income 0.21 0.18 Interest Expense 0.15 0.14 Total Per-Unit Costs $2.15 $1.98
The higher per-unit rates of lease and well, taxes other than income, G&A and interest expense for the six-month period ended June 30, 2003 compared to the same period in 2002 were due primarily to the reasons delineated in the above discussion. The higher per-unit DD&A rate for the six-month period ended June 30, 2003 compared to the same period in 2002 was due primarily to increased production from higher cost properties in Canada, and the Corpus Christi, Oklahoma City and Midland Divisions. The rate was also affected by changes in the Canadian exchange rate and the reduced reserve estimate for a certain offshore field. SFAS No. 143 accretion expense increased the DD&A rate by $0.01 per Mcfe in the first half of 2003. PART I. FINANCIAL INFORMATION (Continued) ITEM 2. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS - (Continued) EOG RESOURCES, INC. Income Tax Provision. For the first half of 2003, income tax provision increased $125 million to $131 million compared to the first half of 2002 due to increases of both the pre-tax income and the effective tax rate. The increase in the effective tax rate for the first half of 2003 to 35% from 29% for the same period of 2002 was due primarily to the expiration of the Section 29 Credit provision in the Internal Revenue Code as of December 31, 2002 and increases in the overall foreign effective tax rate. Capital Resources and Liquidity EOG's primary sources of cash during the six months ended June 30, 2003 included funds generated from operations, proceeds from sales of partial interests in certain equity investments and proceeds from stock options exercised. Primary cash outflows included funds used in operations, exploration and development expenditures, repayment of debt, common stock repurchases and dividends paid to EOG shareholders. Net operating cash flows of $653 million for the first six months of 2003 increased approximately $379 million as compared to the first six months of 2002 primarily reflecting higher operating revenues, partially offset by higher cash operating expenses. Net investing cash outflows of approximately $357 million for the first six months of 2003 decreased by $87 million versus the comparable prior year period due primarily to lower exploration and development expenditures, including property acquisitions, and favorable changes in working capital related to investing activities. 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. Exploration and development expenditures for the first six months of 2003 and 2002 are as follows (in millions):
Six Months Ended June 30, 2003 2002 United States $ 298 $ 266 Canada 54 106 North America 352 372 Trinidad 10 31 United Kingdom 11 - Other 2 1 Subtotal 375 404 Deferred Income Tax Gross Up - 11 TOTAL $ 375 $ 415
PART I. FINANCIAL INFORMATION (Continued) ITEM 2. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS - (Continued) EOG RESOURCES, INC. Total exploration and development expenditures of $375 million for the first six months of 2003 were $40 million lower than the prior year period due primarily to decreased development and exploratory activities in Canada and Trinidad and decreased producing property acquisitions in Canada, partially offset by increased development and exploratory activities in the United States. The 2003 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 2002 expenditures of $415 million included $256 million in development, $99 million in exploration, $44 million in property acquisitions, $11 million in deferred income tax gross up and $5 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. Cash used by financing activities was $155 million for the first six months of 2003 versus cash provided of $177 million for the comparable prior year period. Financing activities for 2003 included the repayment of the outstanding balances of commercial paper borrowings and the uncommitted line of credit of $120 million and $14 million, respectively, repurchases of EOG's common stock of $21 million, cash dividends payments of $15 million and proceeds of $15 million from sales of treasury stock attributable to employee stock option exercises and the employee stock purchase plan. At June 30, 2003 and December 31, 2002, EOG had cash and cash equivalents of $151 million and $10 million, respectively. 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. As more fully discussed in Note 11 to the consolidated financial statements included in EOG's 2002 Annual Report, EOG engages in price risk management activities from time to time. Derivative financial instruments (primarily price swaps and collars) are utilized selectively to hedge the impact of market fluctuations on natural gas and crude oil prices. During the first six months of 2003 and 2002, EOG elected not to designate any of its price risk management activities as accounting hedges, and accordingly, accounted for them using the mark-to-market accounting method. At June 30, 2003, EOG had outstanding natural gas financial collar contracts that set floor prices that averaged $3.83 per million British thermal units ("MMBtu") and ceiling prices that averaged $5.35 per MMBtu covering notional volumes of 125,000 MMBtu per day of natural gas for the period July 2003 through December 2003. At June 30, 2003, the fair value of these natural gas financial collar contracts was a negative $14 million. At June 30, 2003, EOG had outstanding natural gas financial price swap contracts covering net notional volumes of 100,000 MMBtu per day of natural gas for July 2003 at an average price of $4.77 per MMBtu and 75,000 MMBtu per day of natural gas for the period August 2003 through October 2003 at an average price of $4.43 per MMBtu. At June 30, 2003, the fair value of these natural gas financial price swap contracts was a negative $10 million. PART I. FINANCIAL INFORMATION (Continued) ITEM 2. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS - (Concluded) EOG RESOURCES, INC. At June 30, 2003, EOG had outstanding crude oil financial price swap contracts covering notional volumes of five MBbl per day of crude oil for the period July 2003 through December 2003 at an average price of $25.11 per barrel. At June 30, 2003, the fair value of these crude oil financial price swap contracts was a negative $4 million. 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; 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 such activities; acts of war; 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 I. FINANCIAL INFORMATION (Concluded) ITEM 4. CONTROLS AND PROCEDURES EOG RESOURCES, INC. Based on an evaluation of the disclosure controls and procedures conducted within 90 days prior to the filing date of this report on Form 10-Q, the Chairman of the Board and Chief Executive Officer, Mark G. Papa, and the President and Chief of Staff, and Principal Financial Officer, Edmund P. Segner, III, have concluded that the disclosure controls and procedures (as defined in Rules 13a-14(c) and 15d-14(c) promulgated under the Securities Exchange Act of 1934) are effective. There were no significant changes in the internal controls or in other factors that could significantly affect those controls subsequent to the date of the evaluation thereof. 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 4. Submission of Matters to a Vote of Security Holders The Annual Meeting of Shareholders of EOG Resources, Inc. was held on May 6, 2003, in Houston, Texas, for the purpose of electing a board of directors and ratifying the appointment of auditors. 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 101,407,606 2,506,552 Charles R. Crisp 101,408,791 2,505,367 Mark G. Papa 102,073,397 1,840,761 Edward Randall, III 101,406,909 2,507,249 Edmund P. Segner, III 102,376,558 1,537,600 Donald F. Textor 101,417,066 2,497,092 Frank G. Wisner 101,408,107 2,506,051
(b) The appointment of Deloitte & Touche LLP, independent public accountants, as auditors for the year ending December 31, 2003 was ratified by the following vote: 102,030,767 shares for; 1,340,822 shares against; and 542,570 shares abstaining. PART II. OTHER INFORMATION (Concluded) EOG RESOURCES, INC. 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 2003, EOG filed the following Current Reports on Form 8-K: - On April 9, 2003, to report the preapproval for retention of Deloitte & Touche LLP to provide audit services for the year ending December 31, 2003 and other services for the calendar year 2003 in Item 5 - Other Information, to provide updated summaries of the outstanding 2003 natural gas and crude oil financial price swap and natural gas financial collar contracts and to report anticipated results of the price risk management activities for the first quarter of 2003 in Item 9 - Regulation FD Disclosure. - On May 5, 2003, to provide estimates for the second quarter and full year 2003 and to provide updated summaries of the outstanding 2003 natural gas and crude oil financial price swap and natural gas financial collar contracts in Item 9 - Regulation FD Disclosure. - On May 5, 2003, to report the issuance of the press release for the first quarter 2003 financial and operational results in Item 9 - Regulation FD Disclosure. 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 7, 2003 By: /s/ TIMOTHY K. DRIGGERS Timothy K. Driggers Vice President, Accounting and Land Administration (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