UNITED STATES 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 March 31, 2002 Commission file number 1-9735 BERRY PETROLEUM COMPANY (Exact name of registrant as specified in its charter) DELAWARE 77-0079387 (State or other jurisdiction of (I.R.S. Employer incorporation or organization) Identification No.) 5201 Truxtun Avenue, Suite 300, Bakersfield, California 93309-0640 (Address of principal executive offices) (Zip Code) Registrant's telephone number, including area code (661) 616-3900 Former name, Former Address and Former Fiscal Year, if Changed Since Last Report: NONE 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 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 ( ) The number of shares of each of the registrant's classes of capital stock outstanding as of March 31, 2002, was 20,833,601 shares of Class A Common Stock ($.01 par value) and 898,892 shares of Class B Stock ($.01 par value). All of the Class B Stock is held by a shareholder who owns in excess of 5% of the outstanding stock of the registrant. BERRY PETROLEUM COMPANY MARCH 31, 2002 INDEX PART I. Financial Information Page No. Item 1. Financial Statements Condensed Balance Sheets at March 31, 2002 and December 31, 2001 3 Condensed Income Statements for the Three Month Periods Ended March 31, 2002 and 2001 4 Condensed Statements of Comprehensive Income for the Three Month Periods Ended March 31, 2002 and 2001 4 Condensed Statements of Cash Flows for the Three Month Periods Ended March 31, 2002 and 2001 5 Notes to Condensed Financial Statements 6 Item 2. Management's Discussion and Analysis Of Financial Condition and Results of Operations 7 PART II. Other Information 10 Item 6. Exhibits and Reports on Form 8-K 10 SIGNATURES 10 2 BERRY PETROLEUM COMPANY Part I. Financial Information Item 1. Financial Statements Condensed Balance Sheets (In Thousands, Except Share Information) March 31, December 31, 2002 2001 (Unaudited) ASSETS Current Assets: Cash and cash equivalents $ 12,219 $ 7,238 Short-term investments available for sale 594 594 Accounts receivable 9,491 17,577 Prepaid expenses and other 4,505 2,792 -------- -------- Total current assets 26,809 28,201 Oil and gas properties (successful efforts basis), buildings and equipment, net 203,763 203,413 Other assets 882 912 -------- -------- $ 231,454 $ 232,526 ======== ======== LIABILITIES AND SHAREHOLDERS' EQUITY Current liabilities: Accounts payable $ 8,499 $ 11,197 Accrued liabilities 4,797 7,089 Federal and state income taxes payable 5,132 4,078 Fair value of derivatives 2,983 - -------- -------- Total current liabilities 21,411 22,364 Long-term debt 20,000 25,000 Deferred income taxes 32,195 32,009 Shareholders' equity: Preferred stock, $.01 par value; 2,000,000 - - shares authorized; no shares outstanding Capital stock, $.01 par value: Class A Common Stock, 50,000,000 shares Authorized; 20,833,601 shares issued and outstanding at March 31, 2002 208 208 (20,833,094 at December 31, 2001) Class B Stock, 1,500,000 shares authorized; 898,892 shares issued and outstanding (liquidation preference of 9 9 $899) Capital in excess of par value 48,943 48,905 Accumulated other comprehensive income (1,790) - Retained earnings 110,478 104,031 -------- -------- Total shareholders' equity 157,848 153,153 -------- -------- $ 231,454 $ 232,526 ======== ======== The accompanying notes are an integral part of these financial statements. 3 BERRY PETROLEUM COMPANY Part I. Financial Information Item 1. Financial Statements Condensed Income Statements Three Month Periods Ended March 31, 2002 and 2001 (In Thousands, Except Per Share Information) (Unaudited) 2002 2001 Revenues: Sales of oil and gas $ 19,678 $ 30,697 Sales of electricity 7,314 17,218 Interest and other income, net 378 622 -------- -------- 27,370 48,537 Expenses: -------- -------- Operating costs - oil and gas production 8,086 10,640 Operating costs - electricity generation 6,983 17,019 Depreciation, depletion and amortization 3,992 4,779 General and administrative 1,862 1,917 Write-off (recovery) of electricity receivables (3,631) 6,645 Interest 423 1,157 -------- -------- 17,715 42,157 -------- -------- Income before income taxes 9,655 6,380 Provision for income taxes 1,035 1,358 -------- -------- Net income $ 8,620 $ 5,022 ======== ======== Basic net income per share $ .40 $ .23 ======== ======== Diluted net income per share $ .40 $ .23 ======== ======== Cash dividends per share $ .10 $ .10 Weighted average number of shares ======== ======== of capital stock outstanding (used to calculate basic net income per share) 21,732 22,034 Effect of dilutive securities: Stock options 50 46 Other 29 17 -------- -------- Weighted average number of shares of capital stock used to calculate diluted net income per share 21,811 22,097 ======== ======== Condensed Statements of Comprehensive Income Three Month Periods Ended March 31, 2002 and 2001 (in Thousands) 2002 2001 Net income $ 8,620 $ 5,022 Unrealized losses on derivatives, (net of income taxes of $1,193) (1,790) - Reclassification of realized gain on - (441) derivatives, (net of income taxes of $294) -------- -------- Comprehensive income $ 6,830 $ 4,581 ======== ======== The accompanying notes are an integral part of these financial statements. 4 BERRY PETROLEUM COMPANY Part I. Financial Information Item 1. Financial Statements Condensed Statements of Cash Flows Three Month Periods Ended March 31, 2002 and 2001 (In Thousands) (Unaudited) 2002 2001 Cash flows from operating activities: Net income $ 8,620 $ 5,022 Depreciation, depletion and amortization 3,992 4,779 Deferred income tax liability 187 106 Other comprehensive income (loss) (1,790) (441) Other, net 45 (35) -------- -------- Net working capital provided by operating activities 11,054 9,431 Decrease (increase) in accounts receivable, prepaid expenses and other 6,362 (4,246) Decrease in current liabilities (943) (17,498) -------- -------- Net cash provided by (used in) operating activities 16,473 (12,313) Cash flows from investing activities: Capital expenditures (4,333) (1,666) Other, net 17 - -------- -------- Net cash used in investing activities (4,316) (1,666) Cash flows from financing activities: Payment of long-term debt (5,000) - Proceeds from issuance of long-term debt - 45,000 Dividends paid (2,173) (2,203) Other (3) - -------- -------- Net cash (used in) provided by financing activities (7,176) 42,797 Net increase in cash and cash equivalents 4,981 28,818 Cash and cash equivalents at beginning of year 7,238 2,731 -------- -------- Cash and cash equivalents at end of period $ 12,219 $ 31,549 ======== ======== The accompanying notes are an integral part of these financial statements. 5 BERRY PETROLEUM COMPANY Part I. Financial Information Item 1. Financial Statements Notes to Condensed Financial Statements March 31, 2002 (Unaudited) 1. All adjustments which are, in the opinion of management, necessary for a fair presentation of the Company's financial position at March 31, 2002 and December 31, 2001 and results of operations and cash flows for the three month periods ended March 31, 2002 and 2001 have been included. All such adjustments are of a normal recurring nature. The results of operations and cash flows are not necessarily indicative of the results for a full year. 2. The accompanying unaudited financial statements have been prepared on a basis consistent with the accounting principles and policies reflected in the December 31, 2001 financial statements. The December 31, 2001 Form 10-K should be read in conjunction herewith. The year-end condensed balance sheet was derived from audited financial statements, but does not include all disclosures required by accounting principles generally accepted in the United States of America. 3. As of December 31, 2001, the Company was owed $13.5 million by Southern California Edison Company (Edison) for power produced from November 2000 through March 2001. Of this balance, $9.3 million was recorded as collectible receivables at December 31, 2001. On March 1, 2002, Edison paid the Company $13.5 million, representing the total amount due plus interest. The Company recorded $4.2 million in income related to the proceeds received, of which $3.6 million was recorded as recovery of previously written-off electricity receivables, $.5 million was recorded in electricity sales and $.1 million was recorded in interest income. 4. In March 2002, the Company entered into a series of put and call crude oil option contracts with two counterparties, effectively creating a zero cost collar, on 5,000 barrels per day covering the periods April 1, 2002 through March 31, 2003. At March 31, 2002, no amount was owed either party, but due to the change in fair value of the hedging instruments, the Company recorded an after-tax charge of $1.8 million to "Accumulated other comprehensive income" on the Company's balance sheet with an offset to current liabilities. 5. In January 2002, the Company entered into an energy conversion arrangement with an electricity customer for February, March, May and June 2002. Under the terms of the agreement, the Company will sell approximately 25 Mw/hr of electricity to a customer in exchange for a sufficient volume of gas to produce this electricity and the Company's payment of an additional fee. This arrangement minimizes the Company's risk to fluctuating natural gas and electricity prices related to these volumes and provides steam at a cost less than $1/bbl to the Company's heavy oil producing operations. 6. The Company adopted Statement of Financial Accounting Standards (SFAS) No. 144, "Accounting for the Impairment of Disposal of Long-Lived Assets," effective January 1, 2002. This statement superceded SFAS No. 121, "Accounting for the Impairment of Long-Lived Assets and for Long-Lived Assets to be Disposed of." This statement required that long-lived assets that are to be disposed of by sale be measured at the lower of book value or fair value, less costs to sell. The adoption of SFAS No. 144 did not have a material impact on the Company's results of operations or financial position. 6 BERRY PETROLEUM COMPANY Part I. Financial Information Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations Results of Operations The Company earned net income of $8.6 million, or $.40 per share, on revenues of $27.4 million in the first quarter of 2002, up 72% from $5 million, or $.23 per share, on revenues of $48.5 million in the first quarter of 2001 and up 115% from $4 million, or $.19 per share, on revenues of $27.4 million in the fourth quarter of 2001. The quarter's results included the recovery of $3.6 million in electricity sales which were written off in the first quarter of 2001 due to the nonpayment by two of California's major utilities. Had these receivables been paid timely, results would have been approximately $.24 per share and $.39 per share for the first quarter of 2002 and 2001, respectively. The following table presents certain comparative operating data for the first quarter of 2002, the first quarter of 2001 and the fourth quarter of 2001. Three Months Ended Mar 31, Mar 31, Dec 31, 2002 2001 2001 Oil and gas: Net production - BOE/day 13,799 15,289 13,444 Per BOE: Average sales price $ 15.87 $ 22.19 $ 15.25 Operating costs(1) 5.95 7.32 6.50 Production taxes .56 .41 .55 Total operating costs 6.51 7.73 7.05 DD&A 3.21 3.47 3.22 G&A 1.50 1.39 1.37 Interest expense .34 .84 .36 Electricity: Electric power produced - Mwh/day 1,890 1,089 1,988 Average sales price - $/Mwh $ 42.99 $ 175.73 $ 46.25 Fuel gas cost - $/Mmbtu 2.49 15.14 2.44 (1)Including monthly expenses in excess of monthly revenues from cogeneration operations of $.31, $1.09 and $.48 in the three months ended March 31, 2002, March 31, 2001 and December 31, 2001, respectively. Operating income in the first quarter of 2002 was $7.7 million, down from $15.4 million in the first quarter of 2001, but up from $6.7 million in the fourth quarter of 2001. Operating income declined from the first quarter of 2001 primarily due to lower oil sales which declined $11.0 million, or 36%. The reasons for this decline were lower production and lower crude oil prices. The decline was partially offset by lower operating costs which declined by $2.5 million to $8.1 million in the first quarter of 2002 from $10.6 million in the first quarter of 7 2001. DD&A also decreased by $.7 million to $3.9 million from $4.6 million in the first quarter of 2001. The increase in operating income in the first quarter of 2002 compared to the fourth quarter of 2001 was due to a $.7 million decline in operating costs. Production (BOE/day) in the first quarter of 2002 was 13,799, down 1,490, or 10%, from 15,289 in the first quarter of 2001, but up 355, or 3% from 13,444 in the fourth quarter of 2001. Production for the Company reached a peak in the first quarter of 2001. Steam injection from all sources had been maximized for an extended period due to favorable oil prices and steam costs which resulted in higher reservoir temperatures and production responses from the Company's Midway-Sunset and Placerita properties. However, during the first quarter of 2001, steaming of Company properties became uneconomic due to the nonpayment of electricity sales by two California utilities and was, therefore, halted. As a result, production declined rapidly in the second and third quarters of 2001. However, cogeneration produced steaming resumed in late June and conventionally generated steaming resumed in the third quarter of 2001. The decline in production ceased and has rebounded with the increased level of steam volume. Current steam injection is approximately 60,000 barrels per day and current production has increased further to approximately 14,200. The Company anticipates continued improvement in production performance for the balance of 2002 based on current steaming activities and projects 2002 production to average between 14,500 and 15,000. The other major contributor to the decrease in operating income from the first quarter of 2001 was the decrease in the price of crude oil. The average price of crude oil per barrel in the first quarter of 2002 was $15.87, down 28% from $22.19 in the first quarter of 2001. Crude oil postings, which bottomed for this cycle at $11.88 per barrel on January 17, 2002, have since improved to an average of $21.94 on April 30, 2002. The Company anticipates revenue from oil and gas operations will improve in the second quarter of 2002 due to higher production compared to the first quarter of 2002 and the higher crude oil price environment. Operating expenses for the first quarter of 2002 were $8.1 million, or $6.78/BOE, down 24% from $10.6 million, or $7.73/BOE in the first quarter of 2001 and down 7% from $8.7 million, or $7.05/BOE, in the fourth quarter of 2001. The largest factors in the decline were lower cost of natural gas used in steaming and oil treating operations, the conversion of the electricity requirements at the South Midway-Sunset properties to Company produced cogeneration power versus power provided by a utility and other field and facility efficiencies. The Company's average purchase cost of natural gas was $2.49 per Mmbtu in the first quarter of 2002, down 84% from $15.14 per Mmbtu in the first quarter of 2001, but comparable to $2.44 in the fourth quarter of 2001. Due to various factors, California border natural gas prices reached unprecedented and unsustainable high levels in early 2001. DD&A for the first quarter of 2002 was $4.0 million, or $3.21/BOE, down from $4.8 million, or $3.47/BOE, in the first quarter of 2001 and equivalent to $4.0 million in the fourth quarter of 2001. The decrease from the first quarter of 2001 was due primarily to a $.7 million write-off of unamortized costs related to the termination of the Company's power sales contracts in the first quarter of 2001. 8 General and administrative costs in the current quarter were $1.9 million, equivalent to $1.9 million in the first quarter of 2001, but up slightly from $1.7 million in the fourth quarter of 2001. On March 1, 2002, the Company received $13.5 million as payment in full from Southern California Edison Company for the remaining outstanding balance for electricity generation from November 2000 through March 2001. The Company recognized income of $3.6 million for the recovery of the actual receivables, $.1 million in additional interest on the stipulated amount of the receivable and $.5 million in additional capacity revenue for periods in 2001 when the Company was compelled to shut-in its cogeneration plants due to the payment default of the utility. The Company experienced an effective tax rate of 11% for the three-month period ending March 31, 2002 compared to an effective tax rate of 21% for the same period last year. The decrease is primarily a result of anticipated increased EOR capital investment and EOR project steam volumes for 2002 and the lower oil prices received during the three-month period. The Company continues to invest in qualifying enhanced oil recovery projects and anticipates an effective rate for 2002 below 25%. Liquidity and Capital Resources Working capital at March 31, 2002 was $5.4 million, down from $49.4 million in the first quarter of 2001 and $5.8 million at December 31, 2001. Working capital was very high in the first quarter of 2001 due primarily to the drawdown of funds from the Company's line of credit in order to provide operating flexibility for the Company during the California energy crisis. Uses of funds in the first quarter of 2002 included capital expenditures of $4.2 million, payment of long-term debt of $5.0 million and the Company's quarterly dividend of $2.3 million. For the first quarter of 2002, the cash provided by operations was $16.5 million compared to a use of funds of $12.3 million in the first quarter of 2001 and $6.5 million in cash provided by operations in the fourth quarter of 2002. The Company's capital budget program for the year 2002 calls for total firm budget expenditures of $27.1 million. Included in the program is the drilling of 88 new wells of which 15 will be horizontal, 45 workovers and $8.6 million in surface and other improvements. Ten new wells have been drilled to date, including 8 horizontal wells, and 18 workovers have been completed. With firm oil prices, it is currently anticipated that the entire firm budget will be implemented in 2002 and completed during the third quarter. Forward Looking Statements "Safe harbor under the Private Securities Litigation Reform Act of 1995": With the exception of historical information, the matters discussed in this Form 10-Q are forward-looking statements that involve risks and uncertainties. Although the Company believes that its expectations are based on reasonable assumptions, it can give no assurance that its goals will be achieved. Important factors that could cause actual results to differ materially from those in the forward-looking statements herein include, but are not limited to, the timing and extent of changes in commodity prices for oil, gas and electricity, gas transportation availability, the non-existence of a liquid marketplace for electricity purchases and sales within California, competition, environmental risks, litigation uncertainties, drilling, development and operating risks, uncertainties about the estimates of reserves, the prices of goods and services, the availability of drilling rigs and other support services, legislative and/or judicial decisions and other government regulation. 9 BERRY PETROLEUM COMPANY Part II. Other Information Item 6. Exhibits and Reports on Form 8-K None 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. BERRY PETROLEUM COMPANY /s/ Jerry V. Hoffman Jerry V. Hoffman Chairman, President and Chief Executive Officer /s/ Ralph J. Goehring Ralph J. Goehring Senior Vice President and Chief Financial Officer (Principal Financial Officer) /s/ Donald A. Dale Donald A. Dale Controller (Principal Accounting Officer) Date: May 6, 2002 10