UNITED STATES SECURITIES AND EXCHANGE COMMISSION Washington, D.C. 20549 FORM 10-K [X] Annual Report Pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934 For the fiscal year ended December 31, 1994 Commission file number 1-9735 BERRY PETROLEUM COMPANY (Exact name of registrant as specified in its charter) DELAWARE 77-0079387 (State of incorporation (I.R.S. Employer or organization) Identification Number) 28700 Hovey Hills Road Taft, California 93268 (Address of principal executive offices, including zip code) Registrant's telephone number, including area code: (805) 769-8811 Securities registered pursuant to Section 12(b) of the Act: Name of each exchange Title of each class on which registered Class A Common Stock, $.01 par value New York Stock Exchange (including associated stock purchase rights) Securities registered pursuant to Section 12(g) of the Act: 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 for such shorter period that the registrant was required to file such report), and (2) has been subject to such filing requirements for the past 90 days. YES [X] NO [ ] Indicate by check mark if disclosure of delinquent filers pursuant to Item 405 of Regulation S-K is not contained herein, and will not be contained, to the best of registrant's knowledge, in definitive proxy or information statements incorporated by reference in Part III of this Form 10- K or any amendment to this Form 10-K. [ ] As of March 6, 1995, the registrant had 21,033,169 shares of Class A Common Stock outstanding and the aggregate market value of the voting stock held by nonaffiliates was approximately $108,570,000. This calculation is based on the closing price of the shares on the New York Stock Exchange on March 6, 1995 of $9.25. The registrant also had 898,892 shares of Class B Stock outstanding on March 6, 1995, all of which is held by an affiliate of the registrant. DOCUMENTS INCORPORATED BY REFERENCE
Part III is incorporated by reference from the registrant's definitive Proxy Statement for its Annual Meeting of Shareholders to be filed, pursuant to Regulation 14A, no later than 120 days after the close of the registrant's fiscal year. BERRY PETROLEUM COMPANY TABLE OF CONTENTS PART I Page Items 1 and 2. Business and Properties 3 Item 3. Legal Proceedings 11 Item 4. Submission of Matters to a Vote of Security Holders 11 Executive Officers 12 PART II Item 5. Market for Registrant's Common Equity and Related Stockholder Matters 13 Item 6. Selected Financial Data 15 Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations 16 Item 8. Financial Statements and Supplementary Data 20 Item 9. Changes in and Disagreements with Accountants on Accounting and Financial Disclosure 43 PART III Item 10. Directors and Executive Officers of the Registrant 43 Item 11. Executive Compensation 43 Item 12. Security Ownership of Certain Beneficial Owners and Management 43 Item 13. Certain Relationships and Related Transactions 43 PART IV Item 14. Exhibits, Financial Statement Schedules, and Reports on Form 8-K 44 2
Items 1 and 2. Business and Properties Introduction Berry Petroleum Company ("Berry" or "Company"), a Delaware corporation formed in 1985 as the successor to Berry Holding Company and various related entities, is an independent energy company engaged in the business of production, development, exploration, blending and marketing of crude oil and natural gas. Information contained in this report on Form 10-K reflects the business of the Company during the year ended December 31, 1994. The Company's mission is to enhance shareholder value and achieve real asset growth. To achieve this, Berry's corporate strategy is to acquire primarily proved reserves with additional development potential and to increase its proved reserves and production through further development of its existing properties by application of enhanced oil recovery (EOR) methods, advanced reservoir management and developmental drilling. All of the Company's reserves are located in the United States, and the Company continues to focus on opportunities in North America. While the Company has substantial working capital available for acquisitions, the Company will, as necessary, consider long-term debt or issuance of capital stock to finance a sizable purchase. Approximately 89% of the Company's proved reserves are located in the Midway-Sunset field in the San Joaquin Valley in California. The majority of these reserves are on properties owned in fee. Net production from this field in 1994 was 2.9 million barrels of oil equivalent (BOE) or 86% of total 1994 BOE production. The Midway-Sunset field contains predominantly heavy crude oil (under 20 degrees API gravity), the production of which depends substantially on steam injection. Berry utilizes primary, cyclic steaming and steam flooding recovery methods in this field. Production from other fields utilize primary recovery methods. Berry operates substantially all of its principal oil producing properties. Field operations include the initial recovery of the crude oil and its transport through treating facilities into storage tanks. After the treating process is completed, which includes removal of water and solids by mechanical, thermal and chemical processes, the crude oil from the Midway- Sunset, Montalvo and Rincon properties is metered through L.A.C.T. (Lease Automatic Custody Transfer) facilities and transferred into crude oil pipelines owned by other oil companies or transported by truck. 3 Revenues The percentage of revenues by source for the prior three years is as follows: 1994 1993 1992 Sales of oil and gas 95% 97% 96% Interest and other income 5% 3% 4% See Berry's Statements of Operations and accompanying Notes thereto. Marketing The Company believes the market for its crude oil differs substantially from the oil market in the remainder of the country. Two key factors are responsible for lower crude prices in California versus the Mid-Continent. The first is that the Company's crude oil is primarily lower gravity crude oil and must be heated or blended for transport to refineries. In general, lower gravity crude oil results in lower yields of light products, such as gasoline and kerosene, in low conversion refineries. Additional processing, such as coking and catalytic cracking, increases light product yields, but at a higher capital cost per barrel of crude oil refined. The refiner or crude oil buyer generally pays lower prices for such crude oil, as reflected in lower posted and spot prices. The second factor is that current federal law prohibits the export of Alaskan North Slope (ANS) crude oil to foreign countries and, consequently, all ANS crude oil production must go to or by the West Coast which reduces the price of both ANS and California crude oil. This federally mandated policy prevents free market prices on the West Coast. This policy results in California heavy crude price variations not consistent with prevailing changes in market prices in other parts of the country, thus making it difficult to hedge the Company's oil prices. The Company continues to be an advocate of lifting the ban on ANS exports so the Company and other West Coast producers can receive a fair market price for their crude oil. While the Company continues to hold a license to export heavy crude oil, it remains uneconomic to sell crude oil under the license. This license has been renewed annually since 1993 and is now scheduled to expire on December 31, 1995. To provide additional market flexibility, the Company owns and operates a blending facility located near its homebase properties. The Company can process up to approximately 5,000 barrels per day of heavy crude oil through the facility. The Company's heavy crude oil can be blended with lighter crude oils and natural gasolines to produce a blended crude oil of approximately 27 degree API gravity. At times, this blending operation allows the Company to improve the profit margin on the sale of its heavy crude oil. Blending also allows the Company to ship through common carrier pipelines and sell directly to refiners in the Los Angeles basin, the San Francisco Bay area and the Mid-Continent. The Company suspended the blending operations in December 1993 due to the high cost of natural gasoline, the improved demand for the Company's 13 degree heavy crude oil, and the narrowing margin between the posted price of the blended crude oil and the heavy crude oil. Although the Company sold its beginning crude oil inventory in 1994, no blending occurred during the year. The Company has the ability to resume blending operations if warranted by market conditions. 4 Environmental and Other Regulations The operations of Berry are affected in varying degrees by federal, state, regional and local laws and regulations, including laws governing allowable rates of production, well spacing, air emissions, water discharges, endangered species, marketing, pricing, taxes and other laws relating to the petroleum industry. Berry is further affected by changes in such laws and by constantly changing administrative regulations. Berry, as an owner and operator of oil and gas properties, is subject to various federal, state, regional and local laws and regulations relating to discharge of materials into, and protection of, the environment. These laws and regulations may, among other things, impose liability on the owner or the lessee in the case of leased properties for the cost of pollution clean-up resulting from operations, subject the owner or lessee to liability for pollution damages, require suspension or cessation of operations in affected areas, and impose restrictions on the injection of liquids into subsurface aquifers that may contaminate groundwater. Such regulation has increased the length of time and cost of planning, designing, drilling, installing, operating and abandoning the Company's oil and gas wells and other treating facilities. Environmental regulations have an increasing impact upon the Company's operations. The Company estimates that it spends approximately $.3 million on technical and managerial time annually to comply with environmental regulations. In addition, the Company spent approximately $1.1 million for capital projects, repairs and maintenance, and permits related to environmental control facilities in 1994 and anticipates spending approximately $.8 million for similar expenditures in 1995, with additional expenditures required in future years. The Company believes these are necessary business costs in the domestic oil and gas industry. Although environmental requirements do have a substantial impact upon the energy industry, generally these requirements do not appear to affect Berry to any greater or lesser extent than other companies in California and in the domestic industry as a whole. In most cases, foreign produced crude oil enjoys a competitive advantage since foreign environmental regulations of oil producing regions are not nearly as stringent or comprehensive as in the United States and particularly California. Berry's properties in the Rincon and Montalvo areas, particularly facilities located offshore, have significant environmental risks due to their location. Oil leaks that occur offshore generally have a greater environmental impact than those onshore. In Berry's case, a small offshore oil spill could immediately involve significant clean-up, regulatory investigation and penalties, any or all of which could subject the Company to a significant financial burden. In addition to purchasing insurance to cover certain environmental risks, the Company mitigates this exposure by the development and implementation of emergency response and major oil spill contingency plans and, at Rincon, for pipeline shipments only, has installed an automatic emergency shut-down system which minimizes the potential discharge from a pipeline rupture. The Company maintains an on-site spill containment boom and is a member of Clean Seas, an organization with significant experience and resources to contain and minimize the effects of an oil spill. 5 The Company experienced an oil spill due to a ruptured pipe on its West Montalvo field in December 1993 which required cleanup of the area directly around the pipe as well as the nearby ocean and an agricultural runoff pond. A regulatory investigation is proceeding and the Company is potentially subject to fines and penalties (see Item 3. "Legal Proceedings" and Item 7. "Management's Discussion and Analysis of Financial Condition and Results of Operations"). The Company notified the California Regional Water Quality Control Board that it had discovered evidence of the presence of petroleum hydrocarbons in the groundwater underlying the Rincon Facilities. The Company initiated an investigation to determine the boundaries of the affected groundwater. The investigation to date has shown that the contamination is below actionable levels. The Company will continue to monitor the situation and intends to request a resolution of "no further action required" from the appropriate review division. The Company is not aware of any unrecorded environmental claims existing at December 31, 1994 which would have a material impact on the Company's financial condition or results of operations. Competition The oil and gas industry is highly competitive. As an independent producer, the Company does not own any refining or retail outlets. It has little control over the price it receives for its crude oil, and higher costs, fees and taxes assessed at the producer level cannot necessarily be passed on to the Company's customers. In exploration and acquisition activities, significant competition is faced since integrated companies, independent companies and individual producers and operators are active bidders for desirable oil and gas properties. Although many of these competitors have greater financial and other resources than the Company, Management believes that it is in a position to compete effectively. Employees The Company had 92 employees at December 31, 1994. Oil and Gas Properties The Company spent a total of $1 million on property acquisitions, $4.7 million on development programs and $1.7 million on exploration programs in 1994. The Company's 1995 budget for capital expenditures on development and exploration activities during 1995 is $8.7 million. As these activities are influenced by numerous factors, many of which are outside the Company's control, the actual expenditure level may vary considerably from budgeted levels. The principal oil and gas producing properties of Berry are located in Kern County and Ventura County, California. Homebase - Berry owns and operates working interests in thirteen properties containing 905 acres located in the southern portion of the Midway-Sunset field. The Company estimates these properties account for approximately 78% of the Company's proved oil and gas reserves and approximately 77% of its current daily production on February 8, 1995. These properties rely on thermally enhanced oil recovery methods, primarily cyclic 6 steaming. Nine of the thirteen properties are owned in fee and are not burdened by royalties. These nine properties accounted for approximately 71% of Berry's average daily production during 1994 and represent 65% of the Company's proved oil and gas reserves. Berry has a 100% working interest in all the Midway-Sunset properties it operates except one, where the Company owns a 96.875% working interest. In December 1994, the Company purchased two adjacent properties totaling 152 acres which are included in the acreage and reserve totals above. The properties are not currently producing, although a development program is underway on one of the properties. Fairfield Properties - Berry owns and operates approximately 1,344 acres in the northern portion of the Midway-Sunset field which account for approximately 11% of the Company's proved oil and gas reserves and approximately 10% of its daily production on February 8, 1995. These properties rely on thermally enhanced oil recovery methods, primarily cyclic steaming and steam flooding. Berry's interests consist of four fee properties comprising 1,009 acres and six leases comprising 335 acres. McKittrick 21Z - Berry owns and operates 468 acres located near the historic McKittrick townsite in Kern County, California which account for approximately 3% of the Company's proved oil and gas reserves and less than 1% of its daily production on February 8, 1995. Rincon - Berry operates two private leases and four leases owned by the State of California in the Rincon field in Ventura County, California. These leases entitle the Company to a 100% working interest in oil and gas wells located on approximately 1,631 acres. Berry estimates that its Rincon properties currently account for 2% of its proved oil and gas reserves and approximately 3% of its daily production on February 8, 1995. These properties rely on primary production methods. West Montalvo - Berry owns 100% of the working interest in six leases in Ventura County, California in the West Montalvo field. Two of the six leases are owned by the State of California. The Company estimates current proved reserves from West Montalvo account for approximately 5% of Berry's proved oil and gas reserves. Total production from these leases, containing 8,563 acres, represents approximately 8% of Berry's total current daily oil and gas production on February 8, 1995. Other - The Company has interests in certain other properties located primarily in California, Louisiana and Texas, which it estimates account for less than 1% of the Company's proved oil and gas reserves and approximately 1% of the Company's total oil and gas production. Development Homebase - South Midway-Sunset Field. During 1994, 14 development wells were drilled and 25 wells were deepened and/or repaired. The objective of this work was to maintain productive capacity and develop additional reserves in the Company's single largest asset. On the Ethel D property, one well was hydraulically fractured and steam stimulated in an extension of a successful program begun in 1993. 7 In December 1994, the Company purchased two adjacent properties, increasing homebase reserves by 1.2 million barrels. Development of the main property will be undertaken in 1995 by the initial drilling of 5 to 10 wells. Two major cost saving programs were completed in 1994. These were the installation of a high voltage power substation and a produced water recycling plant to supply water to the steam cogeneration plant. These projects are expected to reduce power costs and steam water supply costs. At December 31, 1992, the Company had an approximate 11% interest in University Cogeneration Partners Ltd. 1985-1, a limited partnership, which owns a cogeneration plant that sells steam to the Company. The Company purchases approximately 12,500 Bbls/day of steam from the facility which is used in the steaming operations of the homebase properties. As of December 1994, the Company increased its partnership interest to approximately 45%. Fairfield - North Midway-Sunset Field. During 1994, the Company drilled two wells in the Potter sand and one well in the Mya sand reservoir. In 1993, seven wells were deepened and a steam drive project was initiated. While initial results were disappointing, the project was suspended prior to maturity due to low crude oil prices. McKittrick - The Company initiated a Tulare zone steamflood in the first quarter of 1993. However, because of low oil prices for revenue and high gas prices for steam generation cost, the steam drive project was shut-in during 1994 and is not expected to resume until the Company can achieve sustained higher oil prices. Montalvo - Development, redrill and remedial well activity were postponed in 1994 while the Company assessed and implemented facility improvements following the late 1993 oil spill. The program to return idle wells to production is expected to resume in 1995. Rincon - Drilling of extended reach wells to develop proven reserves in the western part of the field was deferred from 1994 to 1995 because of marginal oil prices. Exploration The Company participated in the drilling of four exploratory wells in 1994 in which it owned between 12.5% and 25% working interest in each well. California - One wildcat well was drilled and abandoned as a dry hole in December 1994. Texas - A 3D Seismic survey was made of the Company's Tyler/Lexi prospects and yielded a significant improvement in structural interpretation to support the 1994-1995 exploration program. Two 1993 discovery wells became uneconomic due to a significant decline in production and were written off in June 1994. A new well in the prospect was prepared for spud at year end. The Company divested its interests in non-economic oil and gas properties in East Texas during 1994. These properties were previously written down in 1993 by $2.9 million. 8 Louisiana - The Earl Chauvin #1, a 1993 discovery, started gas sales in April 1994. One exploratory well on another prospect was drilled and abandoned as a dry hole in March 1994. Nevada - In 1994, two exploratory wells were drilled and abandoned as dry holes. The Company has four additional prospect wells to drill to fulfill a six well multicompany exploratory program. Oil and Gas Reserves Reserve Reports - The Company engaged DeGolyer and MacNaughton to estimate the proved oil and gas reserves of the Company for the year ended December 31, 1994 for all of the Company's properties and for the years ended December 31, 1993 and 1992 for the Midway-Sunset field and certain properties located in other fields. The reserves for 1993 and 1992 for the Rincon and Montalvo fields were prepared by Babson and Sheppard. The reserves at December 31, 1992 for the Colorado gas properties, which were sold in 1993, were prepared by Reed W. Ferrill & Associates. These three firms (the Petroleum Engineers) were also asked to estimate the future net revenues to be derived from such properties. Each of the Petroleum Engineers is an independent oil and gas reserve engineering firm. In preparing their respective reports for December 31, 1994, 1993 or 1992, each Petroleum Engineer reviewed and examined such geological, economic, engineering and other data provided by the Company as considered necessary under the circumstances applicable to each reserve report. Each Petroleum Engineer also examined the reasonableness of certain economic assumptions regarding estimated operating and development costs and recovery rates in light of economic circumstances as of December 31, 1994, 1993 and 1992. For the Company's operated properties, reserve estimates are filed annually with the U.S. Department of Energy. Refer to the Supplemental information about oil and gas producing activities (unaudited) for the Company's oil and gas reserve disclosures. Production The following table sets forth certain information regarding production for the periods indicated: Years ended December 31 1994 1993 1992 Net Annual Production(1): Oil (Mbbls) 3,250 3,617 3,683 Gas (Mmcf) 793 771 1,029 Average Sales Price: Oil (per bbl) $11.61 $11.43 $12.83 Gas (per mcf) 1.87 1.96 1.83 Average Production Cost (per bbl equivalent)(2) 6.28 6.35 5.43 (1) Net production represents production owned by Berry and produced to its interest, less royalty and other similar interests. All oil and gas produced, other than lease fuel needs, is sold at the well site. Berry does not refine any of its production. (2) Equivalent oil and gas information is at a ratio of six thousand cubic feet of natural gas to one barrel ("bbl") of oil. 9 Acreage and Wells At December 31, 1994, the Company's properties accounted for the following developed and undeveloped acres: Developed Acres Undeveloped Acres Gross Net Gross Net California 7,493 7,370 6,812 6,812 Nevada - - 56,768 9,461 Texas 840 277 10,812 3,508 Other 1,170 211 625 156 _______ _______ _______ _______ 9,503 7,858 75,017 19,937 ======= ======= ======= ======= Gross acres represent all acres in which Berry has a working interest; net acres represent Berry's aggregate working interests in the gross acres. Berry currently has 1,615 gross oil wells (1,601 net) and 23 gross gas wells (7 net). Gross wells represent the total number of wells in which Berry has a working interest. Net wells represent the number of gross wells multiplied by the percentages of the working interests owned by Berry. One or more completions in the same bore hole are counted as one well. Any well in which one of the multiple completions is an oil completion is classified as an oil well. Drilling Activity The following table sets forth certain information regarding Berry's drilling activities for the periods indicated: 1994 1993 1992 Gross Net Gross Net Gross Net Exploratory Wells Drilled: Productive (1) 0 0.0 3 0.7 1 0.3 Dry (2) 4 0.8 3 0.5 3 0.9 Development Wells Drilled: Productive (1) 14 14.0 18 18.0 25 25.0 Dry (2) 0 0.0 0 0.0 0 0.0 Total Wells Drilled: Productive (1) 14 14.0 21 18.7 26 25.3 Dry (2) 4 0.8 3 0.5 3 0.9 (1) A productive well is a well that is not a dry well. (2) A dry well is a well found to be incapable of producing either oil or gas in sufficient quantities to justify completion as an oil or gas well. As of March 6, 1995, one exploratory well was being drilled. 10 Title and Insurance The Company is not aware of any defect in the title to any of its principal properties. Notwithstanding the absence of a recent title opinion or title insurance policy, the Company believes it has satisfactory title to these properties, subject to such exceptions as the Company believes are customary and usual in the oil and gas industry and which the Company believes will not materially impair its ability to recover the proved oil and gas reserves or to obtain the resulting economic benefits. The oil and gas business can be hazardous, involving unforeseen circumstances such as blowouts or environmental damage. To address the hazards inherent in the oil and gas business, the Company maintains a comprehensive insurance program.
Item 3. Legal Proceedings On December 25, 1993, a crude oil spill was discovered on the Company's West Montalvo Lease in Ventura County, California. The Company estimates that the total discharge was approximately 2,100 barrels. The Company is aware that certain governmental authorities are currently investigating the circumstances surrounding the spill. The Company paid $.6 million to settle all potential state criminal claims against the Company in August 1994. The Company is working on dealing with all other potential matters, related thereto. As of the date of this report, no actions have been filed against the Company in connection with the spill. The Company is in a dispute with University Cogeneration Partners Ltd, 1985-1, regarding certain costs related to the cogeneration facility operations. The Company is a minority owner of University Cogeneration Partners Ltd, 1985-1, of which the major asset is the cogeneration facility located on the Company's properties. A Demand for Arbitration was filed against the Company in early 1995 and the Company answered and filed a counter Demand for Arbitration, which relates to costs and billings to the Company. While the outcome of these proceedings against the Company cannot be predicted with certainty, Management does not expect these matters to have a material adverse effect on the financial position or results of operations of the Company. The information with respect to the issues before the U.S. Tax Court set forth in Note 8 to the Company's financial statements under Item 8 is incorporated herein by reference.
Item 4. Submission of Matters to a Vote of Security Holders None. 11 EXECUTIVE OFFICERS Listed below are the names, ages (as of December 31, 1994) and positions of the executive officers of Berry and their business experience during the past five years. JERRY V. HOFFMAN, 45, President and Chief Executive Officer since May 1994 and President and Chief Operating Officer from March 1992 until May 1994. Mr. Hoffman was added to the Board of Directors in March 1992. Mr. Hoffman held the Senior Vice President and Chief Financial Officer positions from January 1988 until March 1992. Mr. Hoffman, CPA, has held a variety of other positions with the Company and its prior subsidiaries or successors since February 1985. DONALD A. DALE, 48, Controller since December 1985. Mr. Dale, CPA, was the Controller for Berry Holding Company from September 1985 to December 1985. RALPH J. GOEHRING, 38, Chief Financial Officer since March 1992 and Manager of Taxation from September 1987 until March 1992. Mr. Goehring, CPA, is also the Assistant Secretary for Berry Petroleum Company. CHESTER L. LOVE, 60, Vice President of Engineering since March 1994 and Manager of Engineering from May 1992 to March 1994. Mr. Love was previously a Vice President of Consulting for Scientific Software-Intercomp from 1979 to 1992. KENNETH A. OLSON, 39, Corporate Secretary since December 1985 and Treasurer since August 1988. Mr. Olson, CPA, has held a variety of other positions with the Company and its prior subsidiaries or successors since July 1985. STEVEN J. THOMAS, 44, Manager of Production since March 1993 joined the Company's engineering department in September 1992. Mr. Thomas was an engineering and petroleum consultant from 1990 to 1992 and was employed by Chevron USA from 1979 to 1990 in various drilling, production and facilities engineering positions. 12
Item 5. Market for the Registrant's Common Equity and Related Stockholder Matters Shares of Class A Common Stock (Common Stock) and Class B Stock, referred to collectively as the "Capital Stock", are each entitled to one vote and 95% of one vote, respectively. Each share of Class B Stock is entitled to a $1.00 per share preference in the event of liquidation or dissolution. Further, each share of Class B Stock is convertible into one share of Common Stock at the option of the holder. On December 31, 1991, the Company issued 382,629 shares of unregistered Class A Common Stock and $1,290,000 in cash in exchange for all of the outstanding common stock of Surprise Oil Corporation. The Common Stock issued in the merger was registered in a Form S-3 Registration Statement in 1992 and subsequently deregistered in January 1994. Effective December 31, 1994, the Common Stock issued in the merger can be sold by the shareholders without restriction. Between February 28, 1992 and June 30, 1992, the Company operated an odd- lot purchase program whereby the Company offered to purchase at market price the outstanding shares from holders of less than 100 shares of the Company's Common Stock. The buyback program purchased 10,211 shares from 522 odd-lot shareholders of the Company. In July 1992, the Company initiated the repurchase of up to $5 million of its Class A Common Stock. During 1992, a total of 44,200 shares were purchased by the Company in the repurchase program. No additional shares were purchased in 1993 or 1994 in the repurchase program, which has been suspended. In 1989, the Company adopted a Stockholder Rights Agreement and declared a dividend distribution of one such Right for each outstanding share of Capital Stock on December 22, 1989. Each share of Capital Stock issued after December 22, 1989 includes one Right. The Rights expire on December 8, 1999. See Note 6 of Notes to the Financial Statements. The Company's Class A Common Stock is listed on the New York Stock Exchange under the symbol "BRY". The Class B Stock is not publicly traded. The market data and dividends for 1994 and 1993 are shown below: Cash Low High Dividends 1994 First Quarter $ 8 $ 9 7/8 $ .10 Second Quarter 8 10 3/4 .10 Third Quarter 8 7/8 10 1/4 .10 Fourth Quarter 9 11 3/8 .10 1993 First Quarter $ 11 5/8 $ 13 1/2 $ .15 Second Quarter 11 3/4 14 1/4 .15 Third Quarter 10 7/8 13 1/4 .15 Fourth Quarter 8 1/8 11 3/4 .10 The number of holders of record of the Company's Common Stock and Class B Stock as of March 6, 1995 was approximately 1,030 and 1, respectively. 13 The Company's dividend policy is for the Board of Directors to declare and pay dividends quarterly in March, June, September and December. The dividend level may change as it is subject to Board approval, and such approval is influenced by the price of crude oil, capital commitments and satisfactory financial results. Effective December 1993, the quarterly dividend level was reduced 33% from $.15 per share to $.10 per share. Dividends declared on 4,415,000 shares of certain Common Stock are restricted, whereby 37.5% of the dividends declared on these shares are paid by the Company to the surviving member of a group of individuals, the B group, for as long as this remaining member shall live. 14
Item 6. Selected Financial Data The following table sets forth certain financial information with respect to the Company and is qualified in its entirety by reference to the historical financial statements and notes thereto of the Company included in Item 8, "Financial Statements and Supplementary Data". The statement of operations and balance sheet data included in this table for each of the five years in the period ended December 31, 1994 was derived from the audited financial statements and the accompanying notes to those financial statements.
<TABLE> <CAPTION> 1994 1993 1992 1991 1990 <S> <C> <C> <C> <C> <C> Statement of Operations Data: Operating revenues: Sales of oil and gas $ 39,451 $ 42,843 $ 49,598 $ 43,439 $ 53,664 Blending, net 87 265 (1,262) (1,156) 420 Operating costs (excluding DD&A and exploratory dry hole costs) 21,224 23,790 20,931 20,575 20,208 General and administrative expenses (excluding DD&A) 5,118 5,999 5,511 3,840 6,834 Depletion, depreciation & amortization (DD&A) 7,270 9,983 8,123 5,373 4,217 Net income (loss) (1,129) 32 10,115 16,597 17,656 Net income (loss) per share (1) (.05) - .46 .77 .82 Cash dividends per share .40 .55 .60 .60 .56 Weighted average number of shares outstanding 21,932 21,926 21,915 21,539 21,505 Balance Sheet Data: Working capital $ 38,273 $ 40,418 $ 50,642 $ 54,420 $ 64,057 Shareholders' equity 88,632 98,323 109,690 113,204 104,521 Total assets 118,254 135,159 140,140 145,594 130,554 Operating Data: Capital expenditures 6,934 13,983 12,180 14,028 13,617 Average sales price per barrel of oil 11.61 11.43 12.83 12.44 16.75 Average production cost per BOE 6.28 6.35 5.43 6.03 6.34 Total Production: Oil (Bbls) 3,250 3,617 3,683 3,336 3,114 Gas (Mcf) 793 771 1,029 466 439 Proved reserves: Oil (Bbls) 75,996 72,078 72,434 71,054 65,187 Gas (Mcf) 6,530 5,476 10,003 11,772 20,264 (1) Less than $.01 per share in 1993. 15 </TABLE>
Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations The following discussion provides information on the results of operations for the three years ended December 31, 1994 and the financial condition, liquidity and capital resources as of December 31, 1994, 1993 and 1992. The financial statements of Berry and the notes thereto contain detailed information that should be referred to in conjunction with this discussion. The profitability of the Company's operations in any particular accounting period will be directly related to the average realized prices of oil and gas sold, the type and volume of oil and gas produced and the results of development and exploration activities. The average realized prices of oil and gas will fluctuate from one period to another due to world market conditions and other factors. The California crude oil market is especially sensitive since a significant portion of California's crude oil needs are met by imports from Alaska. The aggregate amount of oil and gas produced may fluctuate based on development and exploration of oil and gas reserves pursuant to current reservoir management plans. Production rates, steam costs and maintenance expenses are expected to be the principal influences on operating costs. Accordingly, the results of operations of the Company may fluctuate from period to period based on the foregoing principal factors, among others. Results of Operations The Company incurred a net loss in 1994 of $1.1 million compared to net income of $32,000 and $10.1 million in 1993 and 1992, respectively. The loss in 1994 was due primarily to three factors. First, the Company recorded $5.4 million of exploratory dryhole costs for certain properties which the Company intends to abandon. Second, the Company recorded an impairment writedown in June 1994 of $2.9 million related to its Poso Creek and Kern Front properties and a producing well at Rincon. This impairment was necessary due to low production, low estimated reserves and continued low oil prices. Third, the Company recorded an additional charge of $1.3 million in June 1994 related to the December 1993 Montalvo oil spill. 1994 1993 1992 Production - BOE Per Day 9,266 10,261 10,530 Average Sales Price - Per BOE $ 11.60 $ 11.43 $ 12.75 Operating Cost - Per BOE $ 6.28 $ 6.35 $ 5.43 Depreciation/Depletion - Per BOE $ 1.96 $ 2.47 $ 2.03 Operating income from producing operations in 1994 was $11.6 million, up 17% from $9.9 million in 1993, but down 45% from $21.2 million in 1992. 16 Production volumes declined 10% and 12% in 1994 from 1993 and 1992, respectively, for a number of reasons. First, in December 1993 the PRC 735 lease in the Montalvo field was shut in due to an oil spill and was not brought back on production until April 1994. Second, the Company shut in a number of marginal wells and reduced the volume of steam injected in its enhanced oil recovery operations where it was uneconomic to continue steaming at the low price levels experienced in early 1994. Third, the PRC 1466 lease (Rincon Island) was shut down in January to replace an oil shipping line. This lease was not put back on production until July 1994. The average sales price in 1994 of $11.60 was slightly higher than the $11.43 received in 1993, but down 9% from the $12.75 received in 1992. Total operating costs (excluding depletion, depreciation and amortization, "DD&A") in 1994 were down 11% from 1993 and comparable to 1992. The cost of steaming wells represents the largest component of operating costs. In 1994 the Company reduced its steam injection in its homebase, Fairfield and McKittrick properties a total of 24% and 15% from 1993 and 1992, respectively. The Company injected 13,676 bbls/day of steam in 1994 compared to 18,005 bbls/day in 1993 and 16,129 bbls/day in 1992. DD&A of $1.96/BOE in 1994 was down 21% and 3% from 1993 and 1992, respectively. DD&A in 1994 was lower than in 1993 due primarily to the lower depreciable basis resulting from the impairment and dryhole charges recorded in the second quarter of 1994. DD&A in 1993 was higher than in 1992 due to the further development of certain of the Company's properties, which resulted in a higher depreciable asset base, and higher depletion rates used on certain of the Company's properties. To provide additional marketing flexibility for the Company's heavy crude oil production, the Company owns and operates a blending facility located near its homebase properties which can process up to approximately 5,000 barrels per day of heavy crude oil. The Company's heavy crude oil can be blended with lighter crude oil and natural gasolines to produce a blended crude oil of approximately 27 degree API gravity. Blending allows the Company to ship through common carrier pipelines and sell directly to refiners in the Los Angeles basin, the San Francisco Bay Area and the Mid- Continent and, at times, improve the profit margin on the sale of its heavy crude oil. The Company suspended the blending operations in December 1993 due to the high cost of natural gasoline,the improved demand for the Company's heavy crude oil, and the narrowing margin between the posted price of the blended crude oil and the heavy crude oil. The Company sold its beginning crude oil inventory, but did not blend in 1994. Blending operations will resume in the future, if warranted by market conditions. After deducting fixed expenses including labor, line rental, insurance, DD&A, etc., blending and trading operations resulted in a net loss of $.1 million in 1994. 17 General Interest income declined to $1.6 million in 1994 from $1.9 million and $2.8 million in 1993 and 1992, respectively, due primarily to lower average invested cash balances. General and administrative expenses were $5.1 million in 1994, down 15% and 7%, respectively, from $6 million and $5.5 million in 1993 and 1992. The reduction in 1994 was due primarily to lower payroll related costs and other benefits from the Company's 1994 cost reduction activities and lower legal fees. The Company's pre-tax losses incurred in 1994 and 1993 resulted in effective tax benefits of 42% and 102% in 1994 and 1993, respectively, compared to a 36% tax rate in 1992. The most important factor affecting 1994 and 1993 was the impact of certain tax benefits, primarily enhanced oil recovery credits and percentage depletion as applied to the pre-tax losses. Liquidity and Capital Resources Working capital at December 31, 1994 was $38.3 million, down 5% from $40.4 million at December 31, 1993 and 24% from $50.6 million at December 31, 1992. Working capital declined in 1994 because cash was used for capital expenditures of $6.9 million and to pay dividends of $8.8 million ($.40 per share). Cash flow provided by operating activities of $14.6 million was up 33% from $11.0 million in 1993, but down 34% from $22.2 million in 1992. Cash flow was lower in 1994 and 1993 due to lower oil prices compared to 1992. In addition, cash flow in 1994 was negatively impacted by the decline in production in 1994 compared to 1993 and 1992. However, 1994 cash flow also included $1.4 million in income tax refunds with no comparable amounts in 1993 and 1992. The Company has a $1 million Revolving Credit and Term Loan Agreement with a major California bank. There are no outstanding borrowings under this line, and the Company believes it can borrow additional funds should the need arise for future acquisitions or other corporate purposes. One of the Company's objectives each year is to replace the oil and gas produced through acquisitions, exploration or further development of the Company's existing properties. At December 31, 1994, the total proved reserves were 77.1 million BOE, up from 73.0 million BOE at December 31, 1993 and 74.1 million BOE at December 31, 1992. Although the Company produced 3.4 million BOE in 1994, total proved reserves increased 6% from the beginning of the year primarily due to higher oil prices, the acquisition of 1.2 million barrels, and the further development of the Company's properties. Environmental regulations have an increasing impact upon the Company's operations. The Company estimates that it spends approximately $.3 million on technical and managerial time annually to comply with environmental regulations. In addition, the Company spent approximately $1.1 million for capital projects, repairs and maintenance, and permits related to environmental control facilities in 1994 and anticipates spending approximately $.8 million for similar expenditures in 1995, with additional expenditures required in future years. 18 The Company's 1995 capital budget is $9.3 million, up from $5.8 million in 1994. Of the 1995 budget, 59% relates to the development of the Midway Sunset properties, 24% for development of the Rincon properties, 9% for exploration and the remaining 8% for the development of other properties and general projects. The Company continues to be an advocate for lifting the federal ban on Alaska North Slope (ANS) export so the Company and other West Coast producers can receive a fair market price for their crude oil. Management believes the likelihood of passage of legislation lifting the ban has been greatly improved due to the change of members in both the U.S. Senate and House of Representatives and their approach to free trade issues. If such legislation were to become law, the Company could experience a noticeable improvement in the price the Company receives for its crude oil. While the actual effect is uncertain and governed by numerous factors outside the Company's control, Management estimates the increase to be from $.75 to $1.50 per barrel. Impact of Inflation The impact of inflation on the Company has not been significant in recent years because of the relatively low rates of inflation experienced in the United States. 19
tem 8. Financial Statements and Supplementary Data BERRY PETROLEUM COMPANY Index to Financial Statements and Supplementary Data Page Report of Coopers & Lybrand L.L.P., Independent Accountants 21 Balance Sheets at December 31, 1994 and 1993 22 Statements of Operations for the Years Ended December 31, 1994, 1993 and 1992 23 Statements of Shareholders' Equity for the Years Ended December 31, 1994, 1993 and 1992 24 Statements of Cash Flows for the Years Ended December 31, 1994, 1993 and 1992 25 Notes to the Financial Statements 27 Supplemental Information About Oil & Gas Producing Activities 40 Financial statement schedules have been omitted since they are either not required, are not applicable, or the required information is shown in the financial statements and related notes. 20
REPORT OF INDEPENDENT ACCOUNTANTS To the Board of Directors Berry Petroleum Company We have audited the accompanying balance sheets of Berry Petroleum Company as of December 31, 1994 and 1993, and the related statements of operations, shareholders' equity and cash flows for each of the three years in the period ended December 31, 1994. These financial statements are the responsibility of the Company's management. Our responsibility is to express an opinion on these financial statements based on our audits. We conducted our audits in accordance with generally accepted auditing standards. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. An audit includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements. An audit also includes assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audits provide a reasonable basis for our opinion. In our opinion, the financial statements referred to above present fairly, in all material respects, the financial position of Berry Petroleum Company as of December 31, 1994 and 1993, and the results of its operations and its cash flows for each of the three years in the period ended December 31, 1994, in conformity with generally accepted accounting principles. COOPERS & LYBRAND L.L.P. /s/ Coopers & Lybrand L.L.P. February 22, 1995
Los Angeles, California 21 BERRY PETROLEUM COMPANY Balance Sheets December 31, 1994 and 1993 (In Thousands Except Share Information) 1994 1993 ASSETS Current assets: Cash and cash equivalents $ 7,466 $ 9,457 Short-term investments available for sale 27,617 26,967 Accounts receivable 9,471 16,089 Deferred income taxes 3,315 3,154 Prepaid expenses and other 1,073 1,872 _________ _________ Total current assets 48,942 57,539 Oil and gas properties (successful efforts basis), buildings and equipment, net 66,915 75,513 Other assets 2,397 2,107 _________ _________ $ 118,254 $ 135,159 ========= ========= LIABILITIES AND SHAREHOLDERS' EQUITY Current liabilities: Accounts payable $ 6,032 $ 12,397 Accrued liabilities - oil spill 2,946 2,753 Accrued liabilities - other 1,691 1,971 _________ _________ Total current liabilities 10,669 17,121 Deferred income taxes 18,953 19,715 _________ _________ 29,622 36,836 _________ _________ Commitments and contingencies (Notes 7, 8 and 11) 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; 21,033,169 shares issued and outstanding 210 210 Class B Stock, 1,500,000 shares authorized; 898,892 shares issued and outstanding (liquidation preference of $899) 9 9 Capital in excess of par value; 52,852 52,641 Retained earnings 35,561 45,463 _________ _________ Total shareholders' equity 88,632 98,323 _________ _________ $ 118,254 $ 135,159 ========= ========= The accompanying notes are an integral part of these financial statements. 22 BERRY PETROLEUM COMPANY Statements of Operations Years ended December 31, 1994, 1993 and 1992 (In Thousands Except Per Share Data) 1994 1993 1992 Revenues: Sales of oil and gas $ 39,451 $ 42,843 $ 49,598 Blending operations, net 87 265 (1,262) Interest 1,616 1,893 2,812 Gain (loss) on sale of assets 113 (1,100) - Other income, net 68 195 314 ________ ________ ________ 41,335 44,096 51,462 ________ ________ ________ Expenses: Operating costs 21,224 23,790 20,931 Depreciation, depletion & amortization 7,270 9,983 8,123 Impairment of properties 2,915 2,911 - Oil spill costs 1,344 2,004 - Exploratory dry hole costs 5,414 788 916 General and administrative 5,118 5,999 5,511 Interest - - 107 ________ ________ ________ 43,285 45,475 35,588 ________ ________ ________ Income (loss) before income taxes (1,950) (1,379) 15,874 Provision (benefit) for income taxes (821) (1,411) 5,759 ________ ________ ________ Net income (loss) $ (1,129) $ 32 $ 10,115 ======== ======== ======== Net income (loss) per share $ (.05) $ - $ .46 ======== ======== ======== Weighted average number of shares of capital stock used to calculate earnings per share 21,932 21,926 21,915 ======== ======== ======== The accompanying notes are an integral part of these financial statements. 23 BERRY PETROLEUM COMPANY Statements of Shareholders' Equity Years Ended December 31, 1994, 1993 and 1992 (In Thousands Except Per Share Data) Capital in Capital Stock Excess of Retained Shareholders' Class A Class B Par Value Earnings Equity Balances at January 1, 1992 $ 210 $ 9 $ 52,458 $ 60,527 $113,204 Stock retired - - (653) - (653) Stock options exercised - - 172 - 172 Cash dividends declared - $.60 per share - - - (13,148) (13,148) Net income - - - 10,115 10,115 _______ _______ ________ ________ ________ Balances at December 31, 1992 210 9 51,977 57,494 109,690 Stock options exercised - - 664 - 664 Cash dividends declared - $.55 per share - - - (12,063) (12,063) Net income - - - 32 32 _______ _______ ________ ________ ________ Balances at December 31, 1993 210 9 52,641 45,463 98,323 Stock options - - 211 - 211 Cash dividends declared - $.40 per share - - - (8,773) (8,773) Net loss - - - (1,129) (1,129) ________ _______ ________ ________ ________ Balances at December 31, 1994 $ 210 $ 9 $ 52,852 $ 35,561 $ 88,632 ======== ======= ======== ======== ======== The accompanying notes are an integral part of these financial statements. 24 BERRY PETROLEUM COMPANY Statements of Cash Flows Years Ended December 31, 1994, 1993 and 1992 (In Thousands) 1994 1993 1992 Cash flows from operating activities: Net income (loss) $ (1,129) $ 32 $ 10,115 Depletion, depreciation and amortization 7,270 9,983 8,123 (Gain) loss on sale of assets (113) 1,100 - Exploratory dryhole costs 5,090 170 174 Impairment of properties 2,915 2,911 - Increase in deferred income tax liability (762) 1,536 3,641 Other, net 504 (377) (74) ________ ________ ________ Net working capital provided by operating activities 13,775 15,355 21,979 (Increase) decrease in current assets other than cash, cash equivalents and short-term investments 7,256 (9,248) 5,771 Increase (decrease) in current liabilities (6,452) 4,850 (5,581) ________ ________ ________ Net cash provided by operating activities 14,579 10,957 22,169 ________ ________ ________ Cash flows from investing activities: Capital expenditures (6,934) (13,983) (12,180) Purchase of short-term investments (30,524) (15,560) (38,330) Maturities of short-term investments 29,874 30,290 41,018 Other, net (213) (197) 118 ________ ________ ________ Net cash used in investing activities $ (7,797) $ 550 $ (9,374) ________ ________ ________ The accompanying notes are an integral part of these financial statements. 25 BERRY PETROLEUM COMPANY Statements of Cash Flows, Continued Years Ended December 31, 1994, 1993 and 1992 (In Thousands) 1994 1993 1992 Cash flows from financing activities: Dividends paid $ (8,773) $(12,063) $(13,148) Proceeds from exercise of stock options - 664 172 Purchase and retirement of Company's common stock - - (653) Other, net - - (66) ________ ________ ________ Net cash used in financing activities (8,773) (11,399) (13,695) ________ ________ ________ Net increase (decrease) in cash and cash equivalents (1,991) 108 (900) Cash and cash equivalents at beginning of year 9,457 9,349 10,249 ________ ________ ________ Cash and cash equivalents at end of year $ 7,466 $ 9,457 $ 9,349 ======== ======== ======== Supplemental disclosures of cash flow information: Interest paid $ 5 $ 8 $ 107 ======== ======== ======== Income taxes paid $ 484 $ 765 $ 3,230 ======== ======== ======== The accompanying notes are an integral part of these financial statements. 26 BERRY PETROLEUM COMPANY
Notes to the Financial Statements 1. Summary of significant accounting policies Cash and cash equivalents Cash equivalents consist principally of commercial paper and money market funds. The Company considers all highly liquid investments purchased with a remaining maturity of three months or less to be cash equivalents. Cash equivalents of $5,979,000 and $6,169,000 at December 31, 1994 and 1993, respectively, are stated at cost, which approximates market. Short-term investments All short-term investments are classified as available for sale. Short- term investments consist principally of United States treasury notes, corporate notes, state and local municipal bonds and auction market preferred stock with remaining maturities of more than three months at date of acquisition. Such investments are stated at cost, which approximates market. The Company utilizes specific identification in computing realized gains and losses on investments sold. For the three years ended December 31, 1994, realized and unrealized gains and losses were insignificant to the financial statements. United States treasury notes with an aggregate market value of $4,500,000 are pledged as collateral to the California State Lands Commission (SLC) for the estimated future dismantlement, restoration and abandonment of the Company's Rincon leases, and $550,000 of United States treasury notes are pledged as collateral to the SLC as a performance bond on the Company's Montalvo properties. Oil and gas properties, buildings and equipment The Company accounts for its oil and gas exploration and development costs using the successful efforts method. Under this method, costs to acquire mineral interests in oil and gas properties, to drill and complete development wells and drill and complete exploratory wells that find proved reserves are capitalized. Exploratory dryhole costs and other exploratory costs, including geological and geophysical costs, are charged to expense when incurred. The costs of carrying and retaining unproved properties are also expensed when incurred. Depletion of oil and gas producing properties is computed using the units-of-production method. The estimated costs, net of salvage value, of plugging and abandoning oil and gas wells and related facilities are accrued using the units-of-production method and are taken into account in determining depletion, depreciation and amortization expense. Buildings and equipment are recorded at cost. Depreciation is provided on a straight-line basis over estimated useful lives ranging from 5 to 30 years for buildings and improvements and 3 to 10 years for machinery and equipment. When assets are sold, the applicable costs and accumulated depreciation are removed from the accounts and any gain or loss is included in income. Expenditures for maintenance and repairs are expensed as incurred. 27 BERRY PETROLEUM COMPANY Notes to the Financial Statements 1. Summary of significant accounting policies (cont'd) The Company evaluates its oil and gas properties for impairment on a field by field basis. If it is determined through an internal engineering study that the net realizable value of a producing property is lower than its net book value, an impairment allowance will be recorded for the difference. In performing these studies, the Company uses standard industry techniques and considers numerous factors, including but not limited to: production history, the Company's perception of future crude oil and natural gas prices and lease operating expenses, estimated capital expenditures, and the experience of the Company with the specific operations in the particular field or geological area. Income Taxes Income taxes are provided based on the liability method of accounting pursuant to Statement of Financial Accounting Standards (SFAS) No. 109, "Accounting for Income Taxes". The provision for income taxes is based on pretax financial accounting income. Deferred tax assets and liabilities are recognized for the future expected tax consequences of temporary differences between income tax and financial reporting and principally relate to differences in the tax bases of assets and liabilities and their reported amounts, using enacted tax rates in effect for the year in which differences are expected to reverse. If it is more likely than not that some portion or all of a deferred tax asset will not be realized, a valuation allowance is recognized. Earnings per share Earnings per share is computed by dividing net income by the weighted average number of capital shares and dilutive common stock equivalents, if any, outstanding during the year. Postretirement and post employment benefits The Company adopted SFAS No. 106, "Employers' Accounting for Post- retirement Benefits Other Than Pensions" using the immediate recognition method and SFAS No. 112, "Employers' Accounting for Postemployment Benefits," in 1993. The impact of such adoption on the Company's financial statements was immaterial. Reclassifications Certain reclassifications have been made to the 1993 and 1992 financial statements to conform with the 1994 presentation. 28 BERRY PETROLEUM COMPANY Notes to the Financial Statements 2. Fair value of financial instruments Financial instruments consist of cash and short-term investments, whose carrying amounts are not materially different from their fair values because of the short maturity of those instruments. The Company's available-for-sale short-term investments at December 31, 1994 consist primarily of United States treasury notes (62%), corporate notes (27%), and municipal bonds and auction market preferred stock (11%). Of the short-term investments at December 31, 1994, 47% mature in one year or less and 53% mature in 13 to 24 months. The Company has no involvement with derivative financial instruments. 3. Concentration of Credit Risks The Company sells oil, gas and natural gas liquids to pipelines and refineries. Credit is extended based on an evaluation of the customer's financial condition. For the three years ended December 31, 1994 the Company has experienced no credit losses on the sale of oil, gas and natural gas liquids. The Company places its temporary cash investments with high credit quality financial institutions and limits the amount of credit exposure to any one financial institution. For the three years ended December 31, 1994, the Company has not incurred losses related to these investments. The following summarizes the accounts receivable balances at December 31, 1994 and sales activity with significant customers for each of the years ended December 31, 1994, 1993 and 1992 (in thousands): Accounts Sales Receivable For the Year Ended December 31, Customer December 31, 1994 1994 1993 1992 A $ 710 $ 16,027 $ 16,747 $ 4,286 B 1,040 11,319 11,686 20,136 C - - - 6,561 D - - - 4,966 ________ ________ ________ ________ $ 1,750 $ 27,346 $ 28,433 $ 35,949 ======== ======== ======== ======== The loss of any of these customers could have a temporarily adverse impact on the Company's revenues. 29 BERRY PETROLEUM COMPANY Notes to the Financial Statements 4. Oil and gas properties, buildings and equipment Oil and gas properties, buildings and equipment consist of the following at December 31 (in thousands): 1994 1993 Oil and gas: Proved properties: Producing properties, including intangible drilling costs $ 56,216 $ 59,978 Lease and well equipment 67,232 66,925 Unproved properties 383 464 _________ _________ 123,831 127,367 Less accumulated depletion, depreciation and amortization 59,909 55,221 _________ _________ 63,922 72,146 _________ _________ Commercial and other: Land 151 151 Buildings and improvements 3,806 3,785 Machinery and equipment 3,969 3,784 _________ _________ 7,926 7,720 Less accumulation depreciation 4,933 4,353 _________ _________ 2,993 3,367 _________ _________ $ 66,915 $ 75,513 ========= ========= The following sets forth costs incurred for oil and gas property acquisition, exploration and development activities, whether capitalized or expensed (in thousands): 1994 1993 1992 Acquisition of properties $ 1,023 $ - $ 2,311 Exploration 1,701 3,336 1,470 Development 4,678 10,958 9,286 ________ ________ ________ $ 7,402 $ 14,294 $ 13,067 ======== ======== ======== 30 BERRY PETROLEUM COMPANY Notes to the Financial Statements 4. Oil and gas properties, buildings and equipment (cont'd) Results of operations from oil and gas producing and exploration activities The results of operations from oil and gas producing and exploration activities (excluding blending operations, corporate overhead and interest costs) for the three years ended December 31 are as follows (in thousands): 1994 1993 1992 Sales to unaffiliated parties $ 39,451 $ 42,843 $ 49,598 Production costs (21,224) (23,790) (20,931) Exploration expenses (5,414) (788) (916) Depletion, depreciation and amortization (6,627) (9,143) (7,429) ________ ________ ________ 6,186 9,122 20,322 Income tax expenses (1,723) (2,225) (7,373) ________ ________ ________ Results of operations from producing and exploration activities $ 4,463 $ 6,897 $ 12,949 ======== ======== ======== In 1994, the Company recorded an impairment writedown of $2.9 million related to its Poso Creek and Kern Front properties and a producing well at Rincon. Similarly, in 1993 the Company recorded an impairment writedown of $2.9 million related to certain properties in East Texas which were subsequently transferred to another company in December 1994 at no gain or loss to the Company. 5. Debt obligations The Company has a Revolving Credit and Term Loan Agreement (Agreement) with a major California bank. In June 1994 the Company decreased the amount available under this Agreement from $5,000,000 to $1,000,000. The funds from this Agreement can be used for the acquisition of oil and gas properties, other investments, letters of credit and general corporate purposes. At December 31, 1994, the Company had no outstanding borrowings or letters of credit under the Agreement. 6. Shareholders' equity Shares of Class A Common Stock (Common Stock) and Class B Stock, referred to collectively as the "Capital Stock" are each entitled to one vote and 95% of one vote, respectively. Each share of Class B Stock is entitled to a $1.00 per share preference in the event of liquidation or dissolution. Further, each share of Class B Stock is convertible into one share of Common Stock at the option of the holder. 31 BERRY PETROLEUM COMPANY Notes to the Financial Statements 6. Shareholders equity (cont'd) In December 1989, the Company adopted a Stockholder Rights Agreement and declared a dividend distribution of one Right for each outstanding share of Capital Stock. Each Right, when exercisable, entitles the holder to purchase one one-hundredth of a share of a Series A Junior Participating Preferred Stock, or in certain cases other securities, for $38.00. The exercise price and number of shares issuable are subject to adjustment to prevent dilution. The Rights would become exercisable, unless earlier redeemed by the Company, 10 days following a public announcement that a person or group has acquired, or obtained the right to acquire, 20% or more of the outstanding shares of Common Stock or, 10 business days following the commencement of a tender or exchange offer for such outstanding shares which would result in such person or group acquiring 20% or more of the outstanding shares of Common Stock, either event occurring without the prior consent of the Company. The Rights will expire in December 1999 or may be redeemed by the Company at 1 cent per Right prior to that date unless they have theretofore become exercisable. The Rights do not have voting or dividend rights, and until they become exercisable, have no diluting effect on the earnings of the Company. 250,000 shares of the Company's Preferred Stock have been designated Series A Junior Participating Preferred Stock and reserved for issuance upon exercise of the Rights. In July 1992, the Company authorized the repurchase of up to $5 million of its Class A Common Stock. During 1992, a total of 44,200 shares were purchased by the Company. No additional shares were purchased in 1993 or 1994. On February 28, 1992, the Company initiated an odd-lot purchase program whereby the Company offered to purchase the outstanding shares from holders of less than 100 shares of the Company's Common Stock at market price. The odd-lot program, which ended in June 1992, resulted in the purchase of 10,211 shares from 522 odd-lot shareholders of the Company. During 1994, 1993 and 1992, the Company issued -0-, 44,536, and 14,028 shares, respectively, through its Nonstatutory Stock Option Plan. Dividends declared on 4,415,000 shares of certain Common Stock are restricted, whereby 37.5% of the dividends declared on these shares are paid by the Company to the surviving member of a group of individuals, the B Group, as long as this remaining member shall live. 32 BERRY PETROLEUM COMPANY Notes to the Financial Statements 7. Transactions with affiliates University Cogeneration Partners, Ltd. 1985-1 The Company increased its investment in University Cogeneration Partners, Ltd. 1985-1, a limited partnership (the Cogeneration Partnership) to an approximate 45% limited partner interest at December 31, 1994. The Cogeneration Partnership was formed in 1985 to finance the construction of a cogeneration plant on the Company's properties. The Company also committed to purchase the steam generated by the plant and supply the natural gas to fuel the plant. At December 31, 1994 and 1993, the receivable due from the Cogeneration Partnership for natural gas purchases, net of the steam sales to the Company, was $820,000 and $997,000, respectively. The investment of $1,898,000 is accounted for at cost. For the years ended December 31, 1994, 1993 and 1992, the Company recognized as revenue distributions from the Cogeneration Partnership of $0, $72,085 and $146,000, respectively. The Company has committed to purchase the steam generated by the Cogeneration Partnership through 1996 at a target cost which compares favorably to the alternative cost of burning crude oil. Amounts paid by the Company for the steam in 1994, 1993 and 1992 were $4.6 million, $4.3 million and $4.9 million, respectively. To provide water to the cogeneration plant, the Company committed to purchase a minimum of 18,000 barrels of water per day in 1992 through 1994 and 6,333 barrels per day in 1995 from a water district at a cost of $.045 per barrel. Amounts paid by the Company for this water in 1994, 1993 and 1992 were $.4 million, $.3 million and $.3 million, respectively. 8. Income taxes In the first quarter of 1992, the Company adopted SFAS No. 109. The Company previously followed SFAS No. 96. There was no current or cumulative effect of adoption on continuing operations. The provision (benefit) for income taxes consists of the following (in thousands): 1994 1993 1992 Current: Federal $ 158 $ (873) $ 2,497 State (56) (74) 1,052 ________ ________ ________ 102 (947) 3,549 Deferred: Federal (1,077) (369) 1,664 State 154 (95) 546 ________ ________ ________ (923) (464) 2,210 ________ ________ ________ $ (821) $ (1,411) $ 5,759 ======== ======== ======== 33 BERRY PETROLEUM COMPANY Notes to the Financial Statements 8. Income taxes (cont'd) The current deferred tax assets and liabilities are offset and presented as a single amount in the financial statements. Similarly, the noncurrent deferred tax assets and liabilities are presented in the same manner. The following table summarizes the components of the total deferred tax assets and liabilities before such financial statement offsets. The components of the net deferred tax liability are as follows (in thousands): Dec 31, Dec 31, 1994 1993 Federal benefit of state taxes $ 1,334 $ 1,213 Differences between financial reporting and tax bases of assets acquired 3,226 3,256 Net operating loss carryforwards 1,470 2,057 Credit/deduction carryforwards 3,037 1,935 Other, net 712 1,073 Valuation allowance (3,089) (3,089) _________ _________ Total deferred tax asset 6,690 6,445 _________ _________ Depreciation and depletion (16,567) (18,038) State taxes, net (3,795) (3,641) Other, net (1,966) (1,327) _________ _________ Total deferred tax liability (22,328) (23,006) _________ _________ Net deferred tax liability $ (15,638) $ (16,561) ========= ========= 34 BERRY PETROLEUM COMPANY Notes to the Financial Statements 8. Income taxes (cont'd) A reconciliation of the Company's provision for income taxes and the amount computed by applying the U.S. statutory federal income tax rate of 34% to pretax income is as follows (in thousands): 1994 1993 1992 Tax computed at 34% $ (663) $ (469) $ 5,400 Increase (decrease) in taxes resulting from: Asset acquisition/sale differences 394 637 (45) Nontaxable income (171) (323) (154) Percentage depletion (290) (286) (290) State taxes, net 98 (113) 1,203 Enhanced oil recovery, nonconventional fuel tax and alternative minimum tax credits (406) (1,199) (506) Other, net 217 342 151 ________ ________ ________ $ (821) $ (1,411) $ 5,759 ======== ======== ======== Effective Tax Rate (42.1)% (102.3)% 36.3% ======== ======== ======== The Company has $4.3 million of loss carryforwards which may be utilized in future years to reduce the Company's federal income taxes. The expiration dates and amounts are as follows; 1999 - $.4 million, 2000 - $3.9 million. The Company also has approximately $2.5 million of various tax credits and $1.6 million of statutory depletion carryforwards available to reduce future federal income taxes. If not fully utilized, certain enhanced oil recovery tax credits of $1.4 million and $.6 million will expire in the years 2008 and 2009, respectively. The other credits may be carried forward indefinitely. For the years ended December 31, 1987 through 1989, the Internal Revenue Service (IRS) has proposed various adjustments with which the Company disagrees. One issue was settled and three issues went to trial in U.S. Tax Court in April 1993. These issues involved disputes related to 1) a deduction upon expiration of a purchase option, 2) deductibility versus capitalization of litigation costs defending the Company's fiduciary responsibility, and 3) the appropriate IRC 382 limitation associated with a change of ownership upon the stock purchase of an existing corporation. In 1991, the Company paid under protest the proposed assessment of $1.1 million relating to these issues. The Company is awaiting the outcome of this case, which may also impact future years with respect to issues two and three above. The Company believes that adequate accruals have been provided for all years. 35 BERRY PETROLEUM COMPANY Notes to the Financial Statements 9. Stock option and stock appreciation rights plans The Company has a 1987 Nonstatutory Stock Option Plan (the NSO Plan) and a 1987 Stock Appreciation Rights Plan (the SAR Plan). The NSO Plan provides for the granting of options (Options) to purchase up to an aggregate of 700,000 shares of Common Stock. The SAR Plan authorizes a maximum of 700,000 shares of Common Stock which may be subject to stock appreciation rights (SARs). Holders of SARs have the right upon exercise to receive a payment, payable at the discretion of the Compensation Committee in cash or in shares of Common Stock, equal to the amount by which the market price exceeds the Base Price (as defined) with respect to the shares subject to such SARs on the date of exercise. The Base Price with respect to shares subject to SARs still available for grant shall in no case be less than 80% of the fair market value of such shares on the date of grant. All Options and SARs are granted at the discretion of the Board of Directors. The term of each Option or SAR may not exceed ten years from the date of grant. On December 2, 1994, the Board of Directors of the Company adopted, subject to shareholder approval, the Berry Petroleum Company 1994 Stock Option Plan (the 1994 Plan). The 1994 Plan provides for the granting of stock options to purchase up to an aggregate of 1,000,000 shares of Common Stock. All Options, with the exception of the formula grants to non-employee directors, will be granted at the discretion of the Compensation Committee of the Board of Directors. The term of each Option may not exceed ten years from the date the Option is granted. Included in general and administrative expenses is $0 in 1994, $(18,000) in 1993 and $.2 million in 1992 for compensation expense related to the Options and SARs granted to date. The credit in 1993 was due to the decline in the Company's stock price during that year. Because the options issued on December 2, 1994 were all issued at current market value, there is no accounting charge to the Company in connection with the current Option grants. At December 31, 1994 and 1993, the accrued liabilities for the NSO and SAR Plans are $.2 million and $.4 million, respectively. 36 BERRY PETROLEUM COMPANY Notes to the Financial Statements 9. Stock option and stock appreciation rights plans (cont'd) 1994 1993 Options SARs Options SARs Balance outstanding, January 1 142,941 69,020 413,902 213,300 Granted 333,000 - - - Exercised - (5,380) (270,961) (142,980) Canceled/expired (77,800) (23,900) - (1,300) ________ ________ ________ ________ Balance outstanding, December 31 398,141 39,740 142,941 69,020 ======== ======== ======== ======== Balance exercisable at December 31 65,141 39,740 142,941 57,800 ======== ======== ======== ======== Available for future grant 860,800 - 116,000 283,960 ======== ======== ======== ======== Exercise Price $ 9.80 $ 9.80 $ 9.80 $ 9.80 to 10.75 to 10.00 to 10.00 to 10.00 ======== ======== ======== ======== Market price at date $ 10.50 $ 11.63 of exercise $ - to 10.875 $ 13.13 to 13.13 ======== ======== ======== ======== During 1992 41,160 Options and 8,160 SARs were exercised at an exercise price ranging from $9.80 to $10.00 and a market price ranging from $11.13 to $12.88. On December 2, 1994, 300,000 Options were issued to certain key employees at an exercise price of $10.75 per share which was the closing market price of the Company's Class A Common Stock on the New York Stock Exchange on that date. The Options vest 25% per year for four years. The 1994 Plan also allows for Option grants to the Board of Directors under a formula plan whereby all non-employee directors are eligible to receive Options. On December 2, 1994, an aggregate of 33,000 Options (3,000 Options each) were issued to the eleven non-employee directors at an exercise price of $10.75 per share. The Options granted to the non-employee directors vest immediately. The formula plan provides for the annual grant of 3,000 Options to each non-employee director holding office on each December 2nd at the fair market value on the date of grant. The Options granted on December 2, 1994 utilized all 193,800 remaining Options from the 1987 Nonstatutory Stock Option Plan and 139,000 shares from the 1994 Plan. The Board of Directors adopted a resolution to terminate the 1987 Stock Appreciation Rights Plan without utilizing the 307,860 SARs which were still available for issuance. The 39,740 currently outstanding SARs are still available for exercise under the original terms of issuance. 37 BERRY PETROLEUM COMPANY Notes to the Financial Statements 10. Retirement Plan The Company sponsors a defined contribution retirement or thrift plan (401(k) Plan) to assist all employees in providing for retirement or other future financial needs. Employee contributions (up to 6% of their earnings) are matched by the Company dollar for dollar. Effective November 1, 1992, the 401(k) Plan was modified to provide for increased Company matching of employee contributions whereby Company matching contributions will range from 6% to 9% of eligible participating employee earnings, if certain financial results are achieved. For 1994, 1993 and 1992, all matching contributions were at the 6% rate. The Company's contributions to the 401(k) Plan were $.2 million in 1994, $.3 million in 1993 and $.3 million in 1992. 11. Oil Spill On December 25, 1993, the Company experienced a crude oil spill on its PRC 735 State lease located in the West Montalvo field in Ventura County, California. The spill required clean-up of the area directly around the pipe as well as the nearby ocean and an agricultural runoff pond. Working closely with the United States Coast Guard, the California Department of Fish and Game, and other regulatory agencies, the Company substantially completed the clean-up of the spill in January 1994. Certain governmental authorities, including the United States Coast Guard and the California Department of Fish and Game, are currently investigating the circumstances surrounding the spill. The Company negotiated a resolution of the state criminal investigation for a total of $600,000 in August 1994. Investigations continue regarding potential civil and federal criminal penalties, if any. Management believes the Company has an adequate amount of insurance coverage for the majority of the costs associated with the spill and has received preliminary coverage letters from its insurance carriers tendering coverage, subject to certain reservations. Definitive determination will not become known until some time in the future. The Company estimates the total cost of the spill, net of insurance reimbursement, to be a minimum of $3.3 million and a maximum of $5.1 million. Since no other amount in the range is more likely to occur, the minimum amount was expensed by the Company ($1.3 million in the second quarter of 1994 and $2 million in 1993). The costs incurred and estimated to be incurred in connection with the spill not yet paid by the Company are included in accounts payable and accrued liabilities at December 31, 1994, and the probable remaining minimum insurance reimbursement is included in accounts receivable. As of December 31, 1994, the Company had received approximately $7.2 million under its insurance coverage as reimbursement for costs incurred and paid by the Company associated with the spill. 38 BERRY PETROLEUM COMPANY Notes to the Financial Statements 12. Quarterly financial data (unaudited) The following is a tabulation of unaudited quarterly operating results for 1994 and 1993 (in thousands). Certain reclassification have been made to the 1993 columns to conform with the 1994 presentation. Operating Gross Net Income Net Income (Loss) 1994 Revenues Profit (Loss) Per Share First Quarter $ 7,205 $ (18) $ (598) $ (.03) Second Quarter 9,827 (5,916)(A) (4,665) (.21) Third Quarter 11,640 4,602 2,609 .12 Fourth Quarter 10,866 3,141 1,525 .07 _________ _________ _________ _________ $ 39,538 $ 1,809 $ (1,129) $ (.05) ========= ========= ========= ========= 1993 First Quarter $ 10,980 $ 2,361 $ 753 $ .03 Second Quarter 12,428 2,744 344 .02 Third Quarter 11,016 14 (B) (538) (.02) Fourth Quarter 8,684 (973)(C) (527) (.03) _________ _________ _________ _________ $ 43,108 $ 4,146 $ 32 $ - ========= ========= ========= ========= (A) Includes property impairment of $2.9 million and additional oil spill costs accrual of $1.3 million. (B) Includes property impairment of $2.9 million. (C) Includes accrual of oil spill costs of $2.0 million. 39 BERRY PETROLEUM COMPANY Supplemental information about oil & gas producing activities (unaudited) The following estimates of proved oil and gas reserves, both developed and undeveloped, represent interests owned by the Company located solely within the United States. Proved reserves represent estimated quantities of crude oil and natural gas which geological and engineering data demonstrate with reasonable certainty to be recoverable in future years from known reservoirs under existing economic and operating conditions. Proved developed oil and gas reserves are the quantities expected to be recovered through existing wells with existing equipment and operating methods. Proved undeveloped oil and gas reserves are reserves that are expected to be recovered from new wells on undrilled acreage, or from existing wells for which relatively major expenditures are required for completion. Disclosures of oil and gas reserves which follow are based on estimates prepared primarily by independent engineering consultants for the three years ended December 31, 1994. Such estimates are subject to numerous uncertainties inherent in the estimation of quantities of proved reserves and in the projection of future rates of production and the timing of development expenditures. These estimates do not include probable or possible reserves. Changes in estimated reserve quantities The net interest in estimated quantities of proved developed and undeveloped reserves of crude oil and natural gas at December 31, 1994, 1993 and 1992, and changes in such quantities during each of the years then ended were as follows (in thousands): 1994 1993 1992 Oil Gas Oil Gas Oil Gas Mbbls Mmcf Mbbls Mmcf Mbbls Mmcf Proved developed and undeveloped reserves: Beginning of year 72,078 5,476 72,434 10,003 71,054 11,772 Revision of pre- vious estimates 6,002 1,847 3,203 (5,735) 5,058 (1,943) Production (3,250) (793) (3,617) (771) (3,683) (1,029) Discoveries - - 58 1,979 - 109 Purchase of reserves in place 1,166 - - - 5 1,094 _______ _______ _______ _______ _______ _______ End of year 75,996 6,530 72,078 5,476 72,434 10,003 ======= ======= ======= ======= ======= ======= Proved developed reserves: Beginning of year 62,261 4,810 65,516 6,797 58,514 7,359 ======= ======= ======= ======= ======= ======= End of year 62,718 4,727 62,261 4,810 65,516 6,797 ======= ======= ======= ======= ======= ======= 40 BERRY PETROLEUM COMPANY Supplemental information about oil & gas producing activities (unaudited) (cont'd) Standardized measure of discounted future net cash flows from estimated production of proved oil and gas reserves (in thousands): The standardized measure has been prepared assuming year-end sales prices adjusted for fixed and determinable contractual price changes, year- end costs and statutory income tax rates previously legislated, and a ten percent annual discount rate. No deduction has been made for depletion, depreciation or any indirect costs such as general corporate overhead or interest expense. 1994 1993 1992 Future cash inflows $ 960,412 $ 607,137 $ 874,966 Future production and development costs 317,735 473,903 486,751 Future income tax expenses 213,225 37,332 139,445 _________ _________ _________ Future net cash flows 429,452 95,902 248,770 10% annual discount for estimated timing of cash flows 248,499 59,276 147,716 _________ _________ _________ Standardized measure of discounted future net cash flows $ 180,953 $ 36,626 $ 101,054 ========= ========= ========= Average sales prices at December 31: Oil ($/bbl) $ 12.49 $ 8.25 $ 11.85 Gas ($/Mcf) 1.78 2.18 1.53 41 BERRY PETROLEUM COMPANY Supplemental information about oil & gas producing activities (unaudited)(cont'd) Changes in standardized measure of discounted future net cash flows from proved oil and gas reserves (in thousands): 1994 1993 1992 Standardized measure - beginning of year $ 36,626 $101,054 $101,149 ________ ________ ________ Sales of oil and gas produced, net of production costs (18,227) (18,697) (27,282) Revisions to estimates of proved reserves: Net changes in sales prices and production costs 194,099 (110,914) 5,000 Revisions of previous quantity estimates 24,315 2,261 12,214 Change in estimated future development costs (5,470) 6,751 (10,636) Extensions, discoveries and improved recovery less related costs - 2,929 - Purchases of reserves in place 3,815 - 328 Development costs incurred during the period 4,678 10,958 9,285 Accretion of discount 4,602 15,555 15,450 Income taxes (68,416) 36,920 (2,064) Other 4,931 (10,191) (2,390) ________ ________ ________ Net increase (decrease) 144,327 (64,428) (95) ________ ________ ________ Standardized measure - end of year $180,953 $ 36,626 $101,054 ======== ======== ======== 42
tem 9. Changes in and Disagreements with Accountants on Accounting and Financial Disclosure None
Item 10. Directors and Executive Officers of the Registrant The information called for by Item 10 is incorporated by reference from information under the caption "Election of Directors" in the Company's definitive proxy statement to be filed pursuant to Regulation 14A no later than 120 days after the close of its fiscal year. The information on Executive Officers is contained in Part I of this Form 10-K.
Item 11. Executive Compensation The information called for by Item 11 is incorporated by reference from information under the caption "Executive Compensation" in the Company's definitive proxy statement to be filed pursuant to Regulation 14A no later than 120 days after the close of its fiscal year.
Item 12. Security Ownership of Certain Beneficial Owners and Management The information called for by Item 12 is incorporated by reference from information under the caption "Voting Securities" and "Principal Shareholders and Ownership by Management" in the Company's definitive proxy statement to be filed pursuant to Regulation 14A no later than 120 days after the close of its fiscal year. Section 16(a) of the Securities Exchange Act of 1934 requires the Company's executive officers and directors and persons beneficially owning greater than ten percent of the outstanding Shares, to file reports of ownership and changes in ownership with the Securities and Exchange Commission. Based solely on a review of the copies of such forms furnished to the Company, or written representations that no Form 5 was required, the Company believes that all Section 16(a) filing requirements were complied with, except that one report for one transaction was filed late by Mr. Bryant.
Item 13. Certain Relationships and Related Transactions The information called for by Item 13 is incorporated by reference from information under the caption "Certain Relationships and Related Transactions" in the Company's definitive proxy statement to be filed pursuant to Regulation 14A no later than 120 days after the close of its fiscal year. 43
Item 14. Exhibits, Financial Statement Schedules and Reports on Form 8-K A. Financial Statements and Schedules See Index to Financial Statements and Supplementary Data in Item 8. B. Reports on Form 8-K None C. Exhibits Exhibit No. Description of Exhibit Page 3.1* Registrant's Restated Certificate of Incorporation (filed as Exhibit 3.1 to the Registrant's Registration Statement on Form S-1 filed on June 7, 1989, File No. 33-29165) 3.2* Registrant's Restated Bylaws (filed as Exhibit 3.2 to the Registrant's Registration Statement on Form S-1 on June 7, 1989, File No. 33-29165) 3.3* Registrant's Certificate of Designation, Preferences and Rights of Series A Junior Participating Preferred Stock (filed as Exhibit 3.3 to the Annual Report on Form 10-K for the year ended December 31, 1989, File No. 0-11708) 4.1* Rights Agreement between Registrant and Bank of America dated as of December 8, 1989 (filed as Exhibit 1 to Form 8-K filed on December 20, 1989, File No. 0-11708) 10.1* Description of Cash Bonus Plan of Berry Petroleum Company (filed as Exhibit 10.7 to the Annual Report on Form 10-K for the year ended December 31, 1990, File No. 1-9735) 10.2* Energy Supply Agreement dated January 18, 1985, as amended by and between Registrant and University Cogeneration, Inc. (filed as Exhibit 10.10 to the Registration Statement on Form S-4 filed on April 7, 1987, File No. 33-13240) 10.3* Salary Continuation Agreement dated as of March 20, 1987, as amended August 28, 1987, by and between Registrant and Jerry V. Hoffman (filed as Exhibit 10.11 to the Registration Statement on Form S-1 filed on June 7, 1989, File No. 33-29165) 10.4* Form of Salary Continuation Agreements dated as of March 20, 1987, as amended August 28, 1987, by and between Registrant and selected employees of the Company (filed as Exhibit 10.12 to the Registration Statement on Form S-1 filed on June 7, 1989, File No. 33-29165) 10.5* Instrument for Settlement of Claims and Mutual Release by and among Registrant, Victory Oil Company, the Crail Fund and Victory Holding Company effective October 31, 1986 (filed as Exhibit 10.13 to Amendment No. 1 to the Registrant's Registration Statement on Form S-4 filed on May 22, 1987, File No. 33-13240) 44 C. Exhibits (cont'd) Exhibit No. Description of Exhibit Page 10.6* 1987 Nonstatutory Stock Option Plan and 1987 Stock Appreciation Rights Plan as amended March 18, 1988 (filed as Exhibit 10.14 in Registrant's Registration Statement on Form S-8 filed on July 28, 1988, File No. 33-23326) 10.7* Service Contract by and between Registrant and Pride Petroleum Services, Inc. dated November 1, 1989 (filed as Exhibit 10.23 to the Registrant's Annual Report on Form 10-K for the year ended December 31, 1989, File No. 0-11708) 10.8 1994 Stock Option Plan 47 23.1 Consent of Coopers & Lybrand L.L.P. 65 23.2 Consent of Babson and Sheppard 66 23.3 Consent of Reed W. Ferrill & Associates 67 23.4 Consent of DeGolyer and MacNaughton 68 27. ** Financial Data Schedule 69 99.1 Undertaking for Form S-8 Registration Statement 70 99.2* Form of Indemnity Agreement of Registrant (filed as Exhibit 28.2 in Registrant's Registration Statement on Form S-4 filed on April 7, 1987, File No. 33-13240) 99.3* Form of "B" Group Trust (filed as Exhibit 28.3 to Amendment No. 1 to Registrant's Registration Statement on Form S-4 filed on May 22, 1987, File No. 33-13240) * Incorporated by reference ** Included in the Company's electronic filing on EDGAR 45 Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereto duly authorized on March 17, 1995. BERRY PETROLEUM COMPANY /s/ JERRY V. HOFFMAN /s/ RALPH J. GOEHRING /s/ DONALD A. DALE JERRY V. HOFFMAN RALPH J. GOEHRING DONALD A. DALE President and Chief Chief Financial Officer Controller (Principal Executive Officer (Principal Financial Officer) (Accounting Officer) Pursuant to the requirements of the Securities Exchange Act of 1934, this report has been signed below by the following persons on behalf of the registrant and in the capacities on the dates so indicated. Name Office Date /s/ Harvey L. Bryant Chairman of the Board and March 17, 1995 Harvey L. Bryant Director /s/ Jerry V. Hoffman President, Chief Executive March 17, 1995 Jerry V. Hoffman Officer and Director /s/ Benton Bejach Director March 17, 1995 Benton Bejach /s/ William F. Berry Director March 17, 1995 William F. Berry /s/ Gerry A. Biller Director March 17, 1995 Gerry A. Biller /s/ Ralph B. Busch, Jr. Director March 17, 1995 Ralph B. Busch, Jr. /s/ William E. Bush, Jr. Director March 17, 1995 William E. Bush, Jr. /s/ William B. Charles Director March 17, 1995 William B. Charles /s/ Richard F. Downs Director March 17, 1995 Richard F. Downs /s/ John A. Hagg Director March 17, 1995 John A. Hagg /s/ Thomas J. Jamieson Director March 17, 1995 Thomas J. Jamieson /s/ Roger G. Martin Director March 17, 1995 Roger G. Martin 46
EXHIBIT A BERRY PETROLEUM COMPANY 1994 STOCK OPTION PLAN ARTICLE I PURPOSE OF PLAN The purpose of this Plan is to promote the growth and profitability of the Company and other Participating Companies by providing, through the ownership of Options, incentives to attract and retain highly talented persons to provide managerial, administrative and other specialized services to the Company and other Participating Companies and to motivate such persons to use their best efforts on behalf of the Company and other Participating Companies. ARTICLE II DEFINITIONS For purposes of this Plan, the following terms shall have the meanings set forth in this Article II: 2.1 Accrued Installment. The term "Accrued Installment" shall mean any vested installment of an Option. 2.2 Board. The term "Board" shall mean the Board of Directors of the Company. 2.3 Committee. The term "Committee" shall mean the Compensation Committee, or a successor committee, appointed by the Board and constituting not less than two members of the Board, each of whom is a Disinterested Person. A-1 EXHIBIT 10.8 2.4 Company. The term "Company" shall mean Berry Petroleum Company, a Delaware corporation, or any successor thereof. 2.5 Director. The term "Director"
shall mean a member of the Board, or a member of the board of directors of any Participating Company. 2.6 Disinterested Person. The term "Disinterested Person" shall mean any person defined as a Disinterested Person in Rule 16b-3 of the Securities and Exchange Commission as amended from time to time and as promulgated under the Exchange Act. 2.7 Effective Date. The term "Effective Date" shall mean December 2, 1994. 2.8 Eligible Person. The term "Eligible Person" shall mean, except as provided in Section 3.1, any full-time or part- time employee, officer or Director of any Participating Company. 2.9 Exchange Act. The term "Exchange Act" shall mean the Securities Exchange Act of 1934, as amended. 2.10 Fair Market Value. The term "Fair Market Value" shall mean the closing sale price on the trading day in question of the Shares on the Composite Tape for New York Stock Exchange Listed Stocks, or, if the Shares are not quoted on the Composite Tape, on the New York Stock Exchange, or, if the Shares are not listed on such Exchange, on the principal United States securities exchange on which the Shares are listed, or, if the Shares are not listed on any such exchange, the closing bid quotation with respect to the Shares on the trading day in question on the National Association of Securities Dealers, Inc. Automated Quotations Systems or any similar system then in use, or if no A-2 such quotation is available, the fair market value on the date in question of the Shares as determined in good faith by the Committee. If the day in question is not a trading day, the determination of Fair Market Value shall be made as of the nearest preceding trading day. 2.11 Option. The term "Option" shall mean a nonstatutory option to acquire Shares granted under this Plan. 2.12 Optionee. The term "Optionee" shall mean an Eligible Person who has been granted an Option. 2.13 Parent Corporation. The term "Parent Corporation" shall mean a corporation as defined in Internal Revenue Code Section 424(e) or any successor thereto. 2.14 Participating Company. The term "Participating Company" shall mean the Company and any Parent Corporation or Subsidiary Corporation of the Company. 2.15 Plan. The term "Plan" shall refer to the Company's 1994 Stock Option Plan. 2.16 Shares. The term "Shares" shall mean shares of the Company's Class A Common Stock, $.01 par value, and may be unissued shares or treasury shares or shares purchased for purposes of this Plan. 2.17 Subsidiary Corporation. The term "Subsidiary Corporation" shall mean a corporation as defined in Internal Revenue Code Section 424(f) or any successor thereto. 2.18 Terminating Transaction. The term "Terminating Transaction" shall mean any of the following events: (a) the A-3 dissolution or liquidation of the Company; (b) a reorganization, merger or consolidation of the Company with one or more other corporations as a result of which the Company goes out of existence or becomes a subsidiary of another corporation (which shall be deemed to have occurred if another corporation shall own, directly or indirectly, over eighty percent (80%) of the aggregate voting power of all outstanding equity securities of the Company); (c) a sale of all or substantially all of the Company's assets; or (d) a sale of the equity securities of the Company representing more than eighty percent (80%) of the aggregate voting power of all outstanding equity securities of the Company to any person or entity, or any group of persons and entities acting in concert. 2.19 Termination Date. The term "Termination Date" shall mean December 2, 2004. 2.20 Total Disability. The term "Total Disability" shall mean a permanent and total disability as that term is defined in Internal Revenue Code Section 22(e)(3) or any successor thereto. ARTICLE III ADMINISTRATION OF PLAN; GRANT TO DIRECTORS 3.1 Administration by the Committee. This Plan shall be administered by the Compensation Committee of the Board, or its successor (the "Committee"). Subject to the provisions of this Plan document, the Committee shall have full and absolute power and authority in its sole discretion to (i) determine which Eligible Persons shall receive Options, (ii) determine the time when Options shall be granted, (iii) determine the terms and A-4 conditions, not inconsistent with the provisions of this Plan, of any Option granted hereunder, (iv) determine the number of shares subject to or covered by each Option, and (v) interpret the provisions of this Plan and of any Option granted under this Plan. A member of the Committee shall not be an Eligible Person, and shall not have been an Eligible Person at any time within one (1) year prior to appointment to the Committee. Except as otherwise provided herein or otherwise permitted by Rule 16b- 3(c)(3) of the Exchange Act, during said one (1) year prior to such appointment, no member of the Committee shall have been eligible to acquire stock, stock options or stock appreciation rights under any plan of the Company. 3.2 Grant to Non-employee Directors. All non-employee Directors of the Company holding office on December 2, 1994, shall receive a grant of 3,000 Options, conditioned upon the receipt of Shareholder Approval at the 1995 Annual Meeting of Shareholders. For the duration of the 1994 Plan, each non- employee Director holding office on December 2nd of each year shall automatically receive a grant of 3,000 Options. The above referenced Options to non-employee Directors shall be granted upon the following terms and conditions: (a) The exercise price of the Options shall be Fair Market Value on the date of grant. (b) The Options shall vest immediately upon grant. (c) This "formula" grant to non-employee Directors shall not be amended more than once every (6) six months, other than to comport with changes in the Internal Revenue Code, the A-5 Employee Retirement Income Security Act or the rules thereunder. 3.3 Rules and Regulations. The Committee may adopt such rules and regulations as the Committee may deem necessary or appropriate to carry out the purposes of this Plan and shall have authority to take all action necessary or appropriate to administer this Plan. 3.4 Binding Authority. All decisions, determinations, interpretations, or other actions by the Committee shall be final, conclusive, and binding on all Eligible Persons, Optionees, Participating Companies and any successors-in-interest to such parties. ARTICLE IV NUMBER OF SHARES AVAILABLE UNDER THIS PLAN The maximum aggregate number of Shares which may be optioned and sold under this Plan is 1,000,000 Shares. In the event that Options granted under this Plan shall for any reason terminate, lapse, be forfeited, or expire without being exercised, the Shares subject to such unexercised Options may again be subjected to Options under this Plan. In any event, however, no Option may be granted hereunder if the sum of Shares subject to such Option and the number of Shares subject to unexpired Options previously granted hereunder (or subject to unexercised options or stock appreciation rights under any other stock option or stock appreciation right plan of the Company) would exceed twenty percent (20%) of the total shares of voting stock outstanding at such time. A-6 ARTICLE V TERM OF PLAN This Plan shall be effective as of the Effective Date and shall terminate on the Termination Date. No Option may be granted hereunder after the Termination Date. ARTICLE VI OPTION TERMS 6.1 Form of Option Agreement. Any option granted under this Plan shall be evidenced by an agreement ("Option Agreement") in such form as the Committee, in its discretion, may from time to time approve. Any Option Agreement shall contain such terms and conditions as the Committee may deem, in its sole discretion, necessary or appropriate and which are not inconsistent with the provisions of this Plan. 6.2 Vesting and Exercisability of Options. Subject to the limitations set forth herein and/or in any applicable Option Agreement entered into hereunder, Options granted under this Plan shall vest and be exercisable in accordance with the rules set forth in this Section 6.2: a. General. Subject to the other provisions of this Section 6.2, Options shall vest and become exercisable at such times and in such installments as the Committee shall provide in each individual Option Agreement. Notwithstanding the foregoing, the Committee may in its sole discretion accelerate the time at which an Option or installment thereof may be exercised. Unless otherwise provided in this Section 6.2 or in the Option Agreement A-7 pursuant to which an Option is granted, an Option may be exercised when Accrued Installments accrue as provided in such Option Agreement and at any time thereafter until, and including, the Option Termination Date (as defined below). b. Termination of Options. All installments and Options shall expire and terminate on such date as the Committee shall determine ("Option Termination Date"), which in no event shall be later than ten (10) years from the date on which such Option was granted. c. Termination of Eligible Person Status Other Than by Reason of Death or Disability. In the event that the employment of an Eligible Person with a Participating Company is terminated for any reason (other than by reason of death or Total Disability), any installments under an Option held by such Eligible Person which have not accrued as of such termination date shall expire and become unexercisable as of such termination date. Except as otherwise provided herein, in the event that an Eligible Person who is a Director terminates his directorship or otherwise ceases to be a Director for any reason (other than by reason of death or Total Disability), any installments under an Option held by such Eligible Person which have not accrued as of the directorship termination date shall expire and become unexercisable as of the directorship termination date. All Accrued Installments as of the employment termination date and/or the directorship termination date shall remain exercisable only within such period of time as the Committee may determine, but in no event shall any Accrued Installments remain exercisable for a A-8 period in excess of three (3) months following such termination date or for a period in excess of the original Option Termination Date, whichever is earlier. For purposes of this Plan, an Eligible Person who is an employee or Director of any Participating Company shall not be deemed to have incurred a termination of his employment or his directorship (whichever may be applicable) so long as such Eligible Person is an employee or Director (whichever may be applicable) of any Participating Company. d. Leave of Absence. In the case of any employee on an approved leave of absence, the Committee may make such provision respecting continuance of any Options held by the employee as the Committee deems appropriate in its sole discretion, except in no event shall an Option be exercisable after the original Option Termination Date. e. Death or Total Disability of Eligible Person. In the event that the employment or directorship of an Eligible Person with a Participating Company is terminated by reason of death or Total Disability, any unexercised Accrued Installments of Options granted hereunder to such Eligible Person shall expire and become unexercisable as of the earlier of: (1) The applicable Option Termination Date, or (2) The first anniversary of the date of termination of the employment or directorship of such Eligible Person by reason of the Eligible Person's death or Total Disability. Any such Accrued Installments of a deceased Eligible Person may be exercised prior to their expiration only by the A-9 person or persons to whom the Eligible Person's Option rights pass by will or the laws of descent and distribution. Any Option installments under such a deceased or disabled Eligible Person's Option that have not accrued as of the date of the termination of employment, or directorship due to death or Total Disability shall expire and become unexercisable as of such termination date. f. Termination of Affiliation of Participating Company. Notwithstanding the foregoing provisions of this section, in the case of an Eligible Person who is an employee or Director of a Participating Company other than the Company, upon an Affiliation Termination (as defined herein) of such Participating Company such Eligible Person shall be deemed (for all purposes of this Plan) to have incurred a termination of his employment or directorship with such Participating Company for reasons other than death or Total Disability, with such termination to be deemed effective as of the effective date of said Affiliation Termination. As used herein the term "Affiliation Termination" shall mean, with respect to a Participating Company, the termination of such Participating Company's status as a Participating Company (as defined herein) with respect to the Company. 6.3 Options Not Transferable. Options granted under this Plan may not be sold, pledged, hypothecated, assigned, encumbered, gifted or otherwise transferred or alienated in any manner, either voluntarily or involuntarily or by operation of law, other than by will or the laws of descent and distribution, A-10 and (except as specifically provided to the contrary in Section 6.2(e) hereof) may be exercised during the lifetime of an Optionee only by such Optionee. 6.4 Restrictions on Issuance of Shares. a. No Shares shall be issued or delivered upon exercise of an Option unless and until there shall have been compliance with all applicable requirements of the Securities Act of 1933, all applicable listing requirements of any market or securities exchange on which the Company's Common Stock is then listed, and any other requirements of law or of any regulatory body having jurisdiction over such issuance and delivery. The inability of the Company to obtain any required permits, authorizations or approvals necessary for the lawful issuance and sale of any Shares hereunder on terms deemed reasonable by the Committee shall relieve the Company, the Board, and the Committee of any liability in respect of the nonissuance or sale of such Shares as to which such requisite permits, authorizations or approvals shall not have been obtained. b. As a condition to the granting or exercise of any Option, the Committee may require the person receiving or exercising such Option to make any representations and warranties to the Company as may be required or appropriate under any applicable law or regulation, including, but not limited to, a representation that the Option or Shares are being acquired only for investment and without any present intention to sell or distribute such Option or Shares, if such a representation is A-11 required under the Securities Act of 1933 or any other applicable law, rule or regulation. c. The exercise of any Option under this Plan is conditioned on approval of this Plan, within twelve (12) months of the adoption of this Plan by the Board, by (i) the vote of the holders of a majority of the outstanding securities of the Company present, or represented, and entitled to vote at a meeting duly held in accordance with applicable law, or (ii) the written consent of the holders of a majority of the securities of the Company entitled to vote if the requirements of Rule 16b- 3(b)(2) promulgated under the Exchange Act are otherwise satisfied. In the event such shareholder approval is not obtained within such time period, any Options granted hereunder shall be void. 6.5 Option Adjustments. a. If the outstanding Shares are increased, decreased, changed into or exchanged for a different number or kind of shares of the Company through reorganization, recapitalization, reclassification, stock dividend, stock split or reverse stock split, an appropriate and proportionate adjustment shall be made in the number or kind of shares, and the per-share Option price thereof, which may be issued in the aggregate and to any individual Optionee under this Plan upon exercise of Options granted under this Plan; provided, however, that no such adjustment need be made if, upon the advice of counsel, the Committee determines that such adjustment may result in the receipt of federally taxable income to holders of Options granted A-12 hereunder or the holders of Shares or other classes of the Company's securities. b. Upon the occurrence of a Terminating Transaction (as defined in Article II hereof), as of the effective date of such Terminating Transaction, this Plan and any then outstanding Options (whether or not vested) shall terminate unless (i) provision is made in writing in connection with such transaction for the continuance of this Plan and for the assumption of such Options, or for the substitution of such Options of new options covering the securities of the successor or surviving corporation in the Terminating Transaction or an affiliate thereof, with appropriate adjustments as to the number and kind of securities and prices, in which event this Plan and such outstanding Options shall continue or be replaced, as the case may be, in the manner and under the terms so provided; or (ii) the Committee otherwise shall provide in writing for such adjustments as it deems appropriate in the terms and conditions of the then outstanding Options (whether or not vested), including without limitation (A) accelerating the vesting of outstanding Options, and/or (B) providing for the cancellation of Options and their automatic conversion into the right to receive the securities or other properties which a holder of the Shares underlying such Options would have been entitled to receive upon consummation of such Terminating Transaction had such Shares been issued and outstanding (net of the appropriate option exercise prices). If this Plan or the Options shall terminate pursuant to the foregoing provisions of this paragraph (b) because neither (i) A-13 nor (ii) is satisfied, any Optionee holding outstanding Options shall have the right, at such time immediately prior to the consummation of the Terminating Transaction as the Company shall designate, to exercise his or her Options to the full extent not theretofore exercised, including any installments which have not yet become Accrued Installments. c. In all cases, the nature and extent of adjustments under this Section 6.5 shall be determined by the Committee in its sole discretion, and any such determination as to what adjustments shall be made, and the extent thereof, shall be final, binding and conclusive. No fractional shares of stock shall be issued under this Plan pursuant to any such adjustment. 6.6 Taxes. The Committee shall make such provisions and take such steps as it deems necessary or appropriate for the withholding of any federal, state, local and other tax required by law to be withheld with respect to the grant or exercise of an Option under this Plan, including, but without limitation, the withholding of the number of Shares at the time of the grant or exercise of an Option the Fair Market Value of which would satisfy any withholding tax on said exercise or grant, the deduction of the amount of any such withholding tax from any compensation or other amounts payable to an Optionee by any member of the Participating Companies, or requiring an Optionee (or the Optionee's beneficiary or legal representative) as a condition of granting or exercising an Option to pay to any member of the Participating Companies any amount required to be withheld, or to execute such other documents as the Committee A-14 deems necessary or appropriate in connection with the satisfaction of any applicable withholding obligation. 6.7 Legends. Each Option Agreement and each certificate representing Shares acquired upon exercise of an Option shall be endorsed with all legends, if any, required by applicable federal and state securities laws to be placed thereon. The determination of which legends, if any, shall be placed upon Option Agreements and/or said Share certificates shall be made by the Committee in its sole discretion and such decision shall be final, binding and conclusive. ARTICLE VII SPECIAL OPTION TERMS UNDER THIS PLAN 7.1 Option Exercise Price. The Option exercise price for Shares to be issued under this Plan shall be determined by the Committee in its sole discretion, but shall not be less than eighty percent (80%) of the Fair Market Value of the Shares on the date of grant. The date of grant shall be deemed to be the date on which the Committee authorizes the grant of the Option, unless a subsequent date is specified in such authorization. 7.2 Exercise of Options. An Option may be exercised in accordance with this Section 7.2 as to all or any portion of the Shares covered by an Accrued Installment of the Option from time to time during the applicable Option period, except that an Option shall not be exercisable with respect to fractions of a Share. Options may be exercised, in whole or in part, by giving written notice of exercise to the Company, which notice shall specify the number of Shares to be purchased and shall be A-15 accompanied by payment in full of the purchase price in accordance with Section 7.3. An Option shall be deemed exercised when such written notice of exercise and payment has been received by the Company. No Shares shall be issued until full payment has been made and the Optionee has satisfied such other conditions as may be required by this Plan, as may be required by applicable law, rules, or regulations, or as may be adopted or imposed by the Committee. Until the issuance of stock certificates, no right to vote or receive dividends or any other rights as a stockholder shall exist with respect to optioned Shares notwithstanding the exercise of the Option. No adjustment will be made for a dividend or other rights for which the record date is prior to the date the stock certificate is issued, except as provided in Section 6.5. 7.3 Payment of Option Exercise Price. a. Except as otherwise provided in Section 7.3(b), the entire Option exercise price shall be paid in cash at the time the Option is exercised. b. In the discretion of the Committee, an Optionee may elect to pay for all or some of the Optionee's Shares with Common Stock of the Company previously acquired and owned at the time of exercise by the Optionee, subject to all restrictions and limitations of applicable laws, rules and regulations, and subject to the satisfaction of any conditions the Committee may impose, including, but not limited to, the making of such representations and warranties and the providing of such other assurances that the Committee may require with respect to the A-16 Optionee's title to the Company's Common Stock used for payment of the exercise price. Such payment shall be made by delivery of certificates representing the Company's Common Stock, duly endorsed or with duly signed stock power attached, such Common Stock to be valued at its Fair Market Value on the date notice of exercise is received by the Company. ARTICLE VIII AMENDMENT OR TERMINATION OF PLAN 8.1 Board Authority. The Board may amend, alter, and/or terminate this Plan at any time; provided, however, that unless required by applicable law, rule, or regulation or unless no longer required to satisfy the requirements of Rule 16b-3 promulgated under the Exchange Act, the Board shall not amend this Plan without the approval of stockholders (as obtained in accordance with the provisions of Section 6.4(c) hereof) if the amendment would (A) materially increase the benefits accruing to participants under this Plan, (B) materially increase the number of securities which may be issued under this Plan, or (C) materially modify the requirements as to eligibility for participation in this Plan. In determining whether a given amendment is within the scope of (A), (B) or (C), the Company may rely, without limitation, upon the regulations promulgated and the advice provided by the Securities and Exchange Commission with respect to Rule 16b-3. No amendment of this Plan or of any Option Agreement shall affect in a material and adverse manner Options granted prior to the date of any such amendment without the consent of any Optionee holding any such affected Options. A-17 8.2 Contingent Grants Based on Amendments. Options may be granted in reliance on and consistent with any amendment adopted by the Board alone which is necessary to enable such Options to be granted under this Plan, even though such amendment requires future stockholder approval; provided, however, that any such contingent Option by its terms may not be exercised prior to stockholder approval of such amendment and provided, further, that in the event stockholder approval is not obtained within twelve (12) months of the date of grant of such contingent Option, then such contingent Option shall be deemed canceled and no longer outstanding. ARTICLE IX GENERAL PROVISIONS 9.1 Availability of Plan. A copy of this Plan shall be delivered to the Secretary and Assistant Secretary of the Company and shall be shown by the Secretary or Assistant Secretary to any Eligible Person making reasonable inquiry concerning this Plan. 9.2 Notice. Any notice or other communication required or permitted to be given pursuant to this Plan or under Option Agreement must be in writing and shall be deemed to have been given when delivered to and actually received by the party to whom addressed. Notice shall be given to Optionees at their most recent addresses shown in the Company's records. Notice to the Company shall be addressed to the Company at the address of the Company's principal executive offices, to the attention of the Secretary of the Company. 9.3 Titles and Headings. Titles and headings of sections of this Plan are for convenience of reference only and shall not affect the construction of any provision of this Plan. A-18
CONSENT OF INDEPENDENT PUBLIC ACCOUNTANTS We consent to the incorporation by reference in the registration statement of Berry Petroleum Company on Form S-8 (File No. 33-23326) of our report dated February 22, 1995 on our audits of the financial statements of Berry Petroleum Company as of December 31, 1994 and 1993 and for the three years in the period ended December 31, 1994, which report is included in this Annual Report on Form 10-K. COOPERS & LYBRAND L.L.P. /s/ Coopers & Lybrand L.L.P. Los Angeles, California March 17, 1995 Exhibit 23.1
CONSENT OF INDEPENDENT PETROLEUM ENGINEERING CONSULTANT The undersigned, an independent petroleum engineering consultant, hereby consents to incorporation by reference in the Registration Statement No. 33- 23326 on Form S-8 of Berry Petroleum Company and the related Prospectus of our reserve reports prepared pursuant to the Securities Exchange Act of 1934 dated January 26, 1994 and January 29, 1993, pertaining to interest of Berry Petroleum Company and subsidiaries in certain oil and gas properties located in California, and the use of the name Babson and Sheppard Petroleum Engineers as the independent petroleum engineering firm that prepared such reports for the years ended December 31, 1993 and 1992 which reports are referenced in the December 31, 1994 Annual Report on Form 10-K of Berry Petroleum Company. Dated: March 6, 1995 BABSON AND SHEPPARD PETROLEUM ENGINEERS By:/s/ John F. Bergquist John F. Bergquist President Exhibit 23.2
CONSENT OF INDEPENDENT PETROLEUM ENGINEERING CONSULTANT The undersigned, an independent petroleum engineering consultant, hereby consents to incorporation by reference in the Registration Statement No. 33-23326 on Form S-8 of Berry Petroleum Company and the related Prospectus of our reserve report prepared pursuant to the Securities Exchange Act of 1934 dated January 15, 1993, pertaining to interests of Berry Petroleum Company and subsidiaries in certain oil and gas properties located in Colorado, and the use of the name Reed W. Ferrill and Associates as the independent petroleum engineering firm that prepared such report for the year ended December 31, 1992, which report is referenced in the December 31, 1994 Annual Report on Form 10-K of Berry Petroleum Company. Dated: March 6, 1995 REED W. FERRILL AND ASSOCIATES By:/s/Reed W. Ferrill Reed W. Ferrill President Exhibit 23.3
DeGolyer and MacNaughton One Energy Square Dallas, Texas 75206 March 6, 1995 Berry Petroleum Company 28700 Hovey Hills Road Taft, California 93268 Gentlemen: In connection with the Annual Report on Form 10-K of Berry Petroleum Company, hereinafter referred to as the "Company," for the fiscal year ended December 31, 1994, we hereby consent to (i) the use of, and reference to, our report dated February 23, 1995, entitled "Appraisal Report as of December 31, 1994 on Certain Properties owned by Berry Petroleum Company," which pertains to the interests of the Company in certain oil and gas properties located in California, Louisiana, Nevada, and Texas; our report dated March 4, 1994, entitled "Appraisal Report as of December 31, 1993 on Certain Properties owned by Berry Petroleum Company," which pertains to the interests of the Company in certain oil and gas properties located in California, Louisiana, Nevada, and Texas; and our report dated February 12, 1993, entitled "Appraisal Report as of December 31, 1992 on Certain Properties owned by Berry Petroleum Company," which pertains to the interests of the Company in certain oil and gas properties located in California, Louisiana, Nevada and Texas (hereinafter collectively referred
to as the "Reports") under the caption "Oil and Gas Reserves-Reserve Reports" in Items 1 and 2 of such Annual Report, and under the caption"Supplemental Information About Oil and Gas Producing Activities (Unaudited)" in Item 8 of such Annual Report; and (ii) the use of, and reference to, the name DeGolyer and MacNaughton as the independent petroleum engineering firm that prepared the Reports under such captions; provided, however, that since the reserve estimates set forth in the Reports dated March 4, 1994, and February 12, 1993, have been combined with reserve estimates of other petroleum consultants and the engineering staff of the Company for 1993 and 1992, we are necessarily unable to verify the accuracy of the reserve values contained in the aforementioned Annual Report for 1993 and 1992 and, because the cash flow calculations in the Annual Report include estimated income taxes not included in the Reports, we are unable to verify the accuracy of the cash flow values in the Annual Report. Very truly yours, /s/ DeGoyler and MacNaughton DeGOLYER and MacNAUGHTON Exhibit 23.4
<TABLE> <S> <C> <ARTICLE> 5 <LEGEND> THIS SCHEDULE CONTAINS SUMMARY FINANCIAL INFORMATION EXTRACTED FROM THE DECEMBER 31, 1994 FORM 10-K AND IS QUALIFIED IN ITS ENTIRETY BY REFERENCE TO SUCH FINANCIAL STATEMENTS. </LEGEND> <MULTIPLIER> 1,000 <S> <C> <PERIOD-TYPE> YEAR <FISCAL-YEAR-END> DEC-31-1994 <PERIOD-END> DEC-31-1994 <CASH> 7,466 <SECURITIES> 27,617 <RECEIVABLES> 9,471 <ALLOWANCES> 0 <INVENTORY> 0 <CURRENT-ASSETS> 48,942 <PP&E> 131,757 <DEPRECIATION> 64,842 <TOTAL-ASSETS> 118,254 <CURRENT-LIABILITIES> 10,669 <BONDS> 0 <COMMON> 219 <PREFERRED-MANDATORY> 0 <PREFERRED> 0 <OTHER-SE> 88,413 <TOTAL-LIABILITY-AND-EQUITY> 118,254 <SALES> 39,451 <TOTAL-REVENUES> 41,335 <CGS> 0 <TOTAL-COSTS> 33,265 <OTHER-EXPENSES> 10,020 <LOSS-PROVISION> 0 <INTEREST-EXPENSE> 0 <INCOME-PRETAX> (1,950) <INCOME-TAX> (821) <INCOME-CONTINUING> (1,129) <DISCONTINUED> 0 <EXTRAORDINARY> 0 <CHANGES> 0 <NET-INCOME> (1,129) <EPS-PRIMARY> (.05) <EPS-DILUTED> (.05) </TABLE>
UNDERTAKING FOR FORM S-8 REGISTRATION STATEMENT For purposes of complying with the amendments to the rules governing Form S-8 (effective July 13, 1990) under the Securities Act of 1933, the Company hereby undertakes as follows, which undertaking shall be incorporated by reference into the Company's Registration Statement on Form S-8 No. 33-23326 (filed on July 28, 1988): Insofar as indemnification for liabilities arising under the Securities Act of 1933 may be permitted to director, officers and controlling persons of the Company pursuant to the foregoing provisions, or otherwise, the Company has been advised that in the opinion of the Securities and Exchange Commission such indemnification is against public policy as expressed in the Securities Act of 1933 and is, therefore, unenforceable. In the event that a claim for indemnification against such liabilities (other than the payment by the Company of expenses incurred or paid by a director, officer or controlling person of the Company in the successful defense of any action, suit or proceeding is asserted by such director, officer or controlling person in connection with the securities being registered, the Company will, unless in the opinion of
its counsel the matter has been settled by controlling precedent, submit to a court of appropriate jurisdiction the question whether such indemnification is against public policy as expressed in the Act and will be governed by the final adjudication of such issue. Exhibit 99.1