-----BEGIN PRIVACY-ENHANCED MESSAGE----- Proc-Type: 2001,MIC-CLEAR Originator-Name: keymaster@town.hall.org Originator-Key-Asymmetric: MFkwCgYEVQgBAQICAgADSwAwSAJBALeWW4xDV4i7+b6+UyPn5RtObb1cJ7VkACDq pKb9/DClgTKIm08lCfoilvi9Wl4SODbR1+1waHhiGmeZO8OdgLUCAwEAAQ== MIC-Info: RSA-MD5,RSA, fKEXZSRpK621vor1AZa3+cCKle/oCcmbzgpg3/ZjraZBQIkOL4x5OCY1K/2V050V aR7EV62IXBYAuoh6M+wVvw== 0000950134-95-001486.txt : 199506290000950134-95-001486.hdr.sgml : 19950629 ACCESSION NUMBER: 0000950134-95-001486 CONFORMED SUBMISSION TYPE: 424B4 PUBLIC DOCUMENT COUNT: 1 FILED AS OF DATE: 19950628 SROS: AMEX FILER: COMPANY DATA: COMPANY CONFORMED NAME: HOLLY CORP CENTRAL INDEX KEY: 0000048039 STANDARD INDUSTRIAL CLASSIFICATION: PETROLEUM REFINING [2911] IRS NUMBER: 751056913 STATE OF INCORPORATION: DE FISCAL YEAR END: 0731 FILING VALUES: FORM TYPE: 424B4 SEC ACT: 1933 Act SEC FILE NUMBER: 033-59411 FILM NUMBER: 95550309 BUSINESS ADDRESS: STREET 1: 100 CRESCENT COURT STREET 2: STE 1600 CITY: DALLAS STATE: TX ZIP: 75201 BUSINESS PHONE: 2148713555 FORMER COMPANY: FORMER CONFORMED NAME: GENERAL APPLIANCE CORP DATE OF NAME CHANGE: 19680508 424B4 1 FINAL PROSPECTUS DATED JUNE 27, 1995 1 PROSPECTUS PROSPECTUS PURSUANT TO RULE 424(B)(4) OF THE SECURITIES ACT OF 1933, AS AMENDED. REGISTRATION NO. 33-59411 1,000,000 SHARES HOLLY CORPORATION [LOGO] COMMON STOCK ------------------------ All the shares of common stock, par value $.01 per share (the "Common Stock"), of Holly Corporation (the "Company") offered hereby (the "Offering") are being sold by the Selling Stockholders. See "Selling Stockholders." The Company will not receive any of the proceeds from the sale of shares by the Selling Stockholders. The Company's Common Stock is traded on the American Stock Exchange under the symbol "HOC." On June 27, 1995, the last reported sale price of the Common Stock on the American Stock Exchange was $23 1/8 per share. See "Price Range of Common Stock and Dividend Policy." SEE "RISK FACTORS" BEGINNING ON PAGE 9 FOR CERTAIN CONSIDERATIONS RELEVANT TO AN INVESTMENT IN THE COMMON STOCK OFFERED HEREBY. ------------------------ THESE SECURITIES HAVE NOT BEEN APPROVED OR DISAPPROVED BY THE SECURITIES AND EXCHANGE COMMISSION OR ANY STATE SECURITIES COMMISSION NOR HAS THE SECURITIES AND EXCHANGE COMMISSION OR ANY STATE SECURITIES COMMISSION PASSED UPON THE ACCURACY OR ADEQUACY OF THIS PROSPECTUS. ANY REPRESENTATION TO THE CONTRARY IS A CRIMINAL OFFENSE.
- ------------------------------------------------------------------------------------------------------------ - ------------------------------------------------------------------------------------------------------------ PROCEEDS TO PRICE TO UNDERWRITING SELLING PUBLIC DISCOUNT(1) STOCKHOLDERS(2) - ------------------------------------------------------------------------------------------------------------ Per Share...................................... $23.125 $1.15 $21.975 - ------------------------------------------------------------------------------------------------------------ Total(2)....................................... $23,125,000 $1,150,000 $21,975,000 - ------------------------------------------------------------------------------------------------------------ - ------------------------------------------------------------------------------------------------------------
(1) The Company and the Selling Stockholders have agreed to indemnify the several Underwriters against certain liabilities under the Securities Act of 1933, as amended. See "Underwriting." (2) The Selling Stockholders have granted the Underwriters an option, exercisable within 30 days after the date hereof, to purchase up to an additional 150,000 shares of Common Stock solely to cover over-allotments, if any. If such option is exercised in full, the total Price to Public, Underwriting Discount and Proceeds to Selling Stockholders will be $26,593,750, $1,322,500 and $25,271,250, respectively. See "Underwriting." ------------------------ The shares of Common Stock are offered by the several Underwriters, subject to prior sale, when, as and if issued to and accepted by them, and subject to certain other conditions. The Underwriters reserve the right to withdraw, cancel or modify such offer and to reject orders in whole or in part. It is expected that delivery of the shares of Common Stock will be made in New York, New York on or about July 3, 1995. ------------------------ MERRILL LYNCH & CO. CS FIRST BOSTON ------------------------ The date of this Prospectus is June 27, 1995. 2 [PHOTOGRAPH OF THE NAVAJO REFINERY OVER GRAPHIC OF NAVAJO REFINING COMPANY'S MARKETS] 2 3 IN CONNECTION WITH THE OFFERING, THE UNDERWRITERS MAY OVER-ALLOT OR EFFECT TRANSACTIONS WHICH STABILIZE OR MAINTAIN THE MARKET PRICE OF THE COMMON STOCK AT LEVELS ABOVE THOSE WHICH MIGHT OTHERWISE PREVAIL IN THE OPEN MARKET. SUCH TRANSACTIONS MAY BE EFFECTED ON THE AMERICAN STOCK EXCHANGE OR OTHERWISE. SUCH STABILIZING, IF COMMENCED, MAY BE DISCONTINUED AT ANY TIME. AVAILABLE INFORMATION The Company has filed with the Securities and Exchange Commission (the "Commission") a Registration Statement on Form S-3 (together with all amendments and exhibits thereto, the "Registration Statement") under the Securities Act of 1933, as amended (the "Securities Act"), with respect to the Common Stock offered hereby. This Prospectus does not include all the information set forth in the Registration Statement and the exhibits thereto, to which reference is made for further information with respect to the Company. The Company is subject to the informational requirements of the Securities Exchange Act of 1934, as amended (the "Exchange Act"), and the rules and regulations thereunder, and in accordance therewith files periodic reports, proxy and information statements, and other information with the Commission. The Registration Statement and the exhibits thereto and all reports, proxy and information statements, and other information filed by the Company with the Commission may be inspected at the public reference facilities maintained by the Commission at 450 Fifth Street, N.W., Washington, D.C. 20549, and may also be inspected and copied at the regional offices of the Commission located at 7 World Trade Center, 13th Floor, New York, New York 10048 and 500 West Madison Street, Suite 1400, Chicago, Illinois 60661. Copies of such materials may be obtained from the Public Reference Section of the Commission, 450 Fifth Street, N.W., Washington, D.C. 20549, at prescribed rates. The Common Stock is listed on the American Stock Exchange and all reports, proxy and information statements, and other information filed by the Company with the Commission also may be inspected at the American Stock Exchange, 86 Trinity Place, New York, New York 10006. INCORPORATION OF CERTAIN DOCUMENTS BY REFERENCE The following documents filed with the Commission are incorporated into this Prospectus by reference: (1) The Company's Annual Report on Form 10-K for the fiscal year ended July 31, 1994; (2) The Company's Quarterly Report on Form 10-Q for the quarter ended October 31, 1994; (3) The Company's Quarterly Report on Form 10-Q for the quarter ended January 31, 1995; and (4) The Company's Quarterly Report on Form 10-Q for the quarter ended April 30, 1995. All documents filed by the Company pursuant to Sections 13(a), 13(c), 14 or 15(d) of the Exchange Act after the date of this Prospectus and prior to the termination of the Offering shall be deemed to be incorporated by reference in this Prospectus and to be a part hereof from the date of filing of such documents. Any statement contained in a document incorporated or deemed to be incorporated by reference herein shall be deemed to be modified or superseded for purposes of this Prospectus to the extent that a statement contained herein or in any other subsequently filed document which also is or is deemed to be incorporated by reference herein modifies or supersedes such statement. Any such statement so modified or superseded shall not be deemed, except as so modified or superseded, to constitute a part of the Prospectus. The Company will provide without charge to each person, including any beneficial owner of Common Stock, to whom a copy of this Prospectus has been delivered, upon the written or oral request of such person, a copy of any and all of the documents which have been or may be incorporated by reference in this Prospectus, except that exhibits to such documents will not be provided unless they are specifically incorporated by reference into such documents. Requests for copies of any such document should be directed to Holly Corporation, 100 Crescent Court, Suite 1600, Dallas, Texas 75201, Attention: Controller, telephone: (214) 871-3555. 3 4 PROSPECTUS SUMMARY The following summary is qualified in its entirety by the more detailed information and financial statements appearing elsewhere in this Prospectus. Unless otherwise indicated, the information contained in this Prospectus assumes that the Underwriters' over-allotment option is not exercised. Unless the context otherwise requires, the following terms are used herein with the following meanings: (i) the "Company" refers to Holly Corporation and its consolidated subsidiaries, taken as a whole, (ii) "MRC" refers to Montana Refining Company, a Partnership, the general partners of which are wholly-owned subsidiaries of Holly Corporation, (iii) the "Montana Refinery" refers to MRC's refinery near Great Falls, Montana, (iv) "Navajo" refers to Navajo Refining Company, a wholly-owned subsidiary of Holly Corporation and (v) the "Navajo Refinery" refers to Navajo's Artesia and Lovington, New Mexico refining facilities, collectively. THE COMPANY The Company is an independent refiner of petroleum and petroleum derivatives and produces high value light products such as gasoline, diesel fuel and jet fuel for sale primarily in the southwestern United States and northern Mexico. The Company owns a high-conversion petroleum refinery in Artesia, New Mexico, which it operates in conjunction with crude, vacuum distillation and other facilities situated 65 miles away in Lovington, New Mexico. The Navajo Refinery has a crude capacity of 60,000 barrels per day ("BPD") and can process a variety of high sulfur ("sour") crude oils. For the last three fiscal years, sour crude oils have represented approximately 85% of the crude oils processed by the Navajo Refinery. The Navajo Refinery's processing capabilities enable management to vary its crude supply mix to take advantage of changes in raw materials prices and to respond to fluctuations in the availability of crude oil supplies. The Navajo Refinery converts approximately 86% of its raw materials throughput into high value light products. For fiscal 1994, including barrels purchased for resale, gasoline, diesel fuel and jet fuel represented 56.5%, 19.7% and 11.1%, respectively, of Navajo's sales volume. For the last three fiscal years, excluding downtime for scheduled maintenance and turnarounds, the Navajo Refinery has operated at an average annual crude capacity utilization rate of approximately 93%. The Artesia facility is located on a 300-acre site and has fully integrated crude, fluid catalytic cracking ("FCC"), vacuum distillation, alkylation, hydrodesulfurization and reforming units, and approximately 1.5 million barrels of feedstock and product tank storage. The Lovington facility is operated as an integrated component of the Navajo Refinery and refines crude oil into intermediate products, which are transported, primarily via a Company-owned pipeline, to the Artesia facility for further processing. Navajo's assets also include a 500-mile crude oil gathering pipeline system, 30 crude oil and product tank trucks, three refined products pipelines and product storage at terminals in Tucson, Albuquerque, Artesia and El Paso in which the Company has 50% or greater interests. The Company also owns a 7,000 BPD petroleum refinery near Great Falls, Montana, which can process a range of crude oils and which serves primarily the State of Montana. For fiscal 1994, including barrels purchased for resale, gasoline, diesel fuel, asphalt and jet fuel represented 38.6%, 24.3%, 18.6% and 15.7% of MRC's sales volume. For the last three fiscal years, excluding downtime for scheduled maintenance and turnarounds, the Montana Refinery has operated at an average annual crude capacity utilization rate of approximately 94%. In addition to its refining operations, the Company also conducts a small-scale oil and gas exploration and production program. 4 5 Despite fluctuating industry conditions, the Company, which was incorporated in 1947 and acquired the Navajo Refinery in 1969, has generated positive net income for each of the past 24 years. The Company had net income and cash from operating activities of $24.0 million and $33.6 million, respectively, for fiscal 1990, $11.7 million and $27.9 million for fiscal 1991, $2.8 million and $1.0 million for fiscal 1992, $19.0 million and $38.7 million for fiscal 1993, and $20.7 million and $27.7 million for fiscal 1994. The Company believes that it has certain business strengths that have contributed to its history of profitable operations. Among those strengths are the following: - Geographic location/attractive markets. The Navajo Refinery serves primarily the growing southwestern United States market, including El Paso, Albuquerque, Phoenix and Tucson, which generally has favorable supply and demand characteristics compared to Gulf Coast markets, and the northern Mexico market, which is expected to experience demand growth over the next several years. According to data compiled by the United States Bureau of the Census, from April 1, 1990 to July 1, 1993, the population of the Navajo Refinery's principal market area in the U.S. (Arizona, New Mexico and El Paso) grew at a compound annual rate of 2.2%, compared to a nationwide compound annual growth rate of 1.1% during that period. From April 1, 1980 to July 1, 1993, this area grew at a compound annual rate of 2.5%, compared to a nationwide rate of 1.0%. The Montana Refinery serves primarily the State of Montana, which also historically has had relatively favorable supply and demand characteristics. - High conversion refinery. The Navajo Refinery converts approximately 86% of its raw materials throughput into high value light products from a variety of sour crude oils and can vary the refined products it produces to respond to fluctuations in demand. The Navajo Refinery's processing capabilities also enable management to vary its crude supply mix to take advantage of changes in raw materials prices and to respond to fluctuations in the availability of crude oil supplies. For the last three fiscal years, sour crude oils have represented approximately 85% of the crude oils processed by the Navajo Refinery. - Raw material supply. Located on the northwestern shelf of the Permian Basin, the Navajo Refinery has direct access to a historically reliable crude oil supply, which is transported to the refinery primarily through a 500-mile, Company-owned crude oil pipeline gathering system and by crude oil tank trucks. The Company's crude oil pipelines connect to tankage facilities in New Mexico and Texas and are connected to, or are located in proximity to, a number of common carrier crude oil pipelines. The Montana Refinery obtains most of its crude oil via a 93-mile, Company-owned pipeline which runs from near the Canadian border. - Distribution logistics. The Company distributes refined products from the Navajo Refinery to its principal markets primarily through (i) a Company-owned pipeline extending from Artesia to El Paso and (ii) a Company-owned pipeline extending from Artesia to Orla, Texas, and from there west to El Paso. Products can be shipped by pipeline from El Paso to Albuquerque via a products pipeline system owned by Chevron Pipeline Company, and to Tucson and Phoenix via a products pipeline system owned by Santa Fe Pacific Pipeline. The Company also owns a segment of a products pipeline running from Orla to Odessa, Texas, which is currently inactive. The Company believes that the proximity of the Navajo Refinery to its principal markets and the refinery's products distribution network provide a transportation cost advantage over Gulf Coast and West Coast refineries in supplying its markets. 5 6 BUSINESS STRATEGY The Company's strategy has been, and continues to be, to optimize its refinery operations to increase the proportion of high value products it produces and to lower operating costs. As part of this strategy, the Company completed a $63 million expansion of the Navajo Refinery in December 1991, which, among other things, increased its refining capacity from 40,000 to 60,000 BPD. That expansion consisted principally of the addition of a new continuous catalytic regeneration unit, the modification of the FCC unit, the expansion of the naphtha desulfurizer and the installation of new sulphur and alkylation units. The installation of new equipment and the modification and upgrading of existing equipment as part of that expansion program increased the proportion of sour crude oils that the Navajo Refinery can process and increased the proportion of its throughput that can be converted into higher value products. The Company continues to evaluate improvements to its operating cost structure, refineries and crude oil gathering and product distribution systems. Management believes that certain enhancements and additions to the Navajo Refinery should better position the Company to respond to competitive pressures and to meet possible increases in demand for refined products. As part of its strategy, management currently intends to spend approximately $15 million over an 18-month period on identified capital enhancement projects at the Navajo Refinery. Those projects involve upgrades to the FCC and alkylation units, the construction of an isomerization unit and the installation of a new selective hydrogenation process ("SHP") unit. Management expects these projects to increase the Navajo Refinery's total gasoline production and to improve its ability to produce a greater proportion of "premium" (high octane) gasoline. In addition, these enhancements and plant additions are expected to improve management's flexibility to operate using different types of crude oils and other raw materials and to provide a platform for further refinery expansion, if appropriate, in the future. In addition, the Company is evaluating a number of other possible capital improvement projects, including (i) the redistribution of process activities between the Lovington and Artesia facilities in order to realize potential operating and transportation cost savings, (ii) other upgrades to improve the efficiency of the Navajo Refinery, (iii) modifications to increase product pipeline distribution capacity and (iv) product pipeline reconditioning and construction to facilitate entry into new markets. See "Capital Improvement Projects." The Company's executive offices are located at 100 Crescent Court, Suite 1600, Dallas, Texas 75201, and its telephone number at that address is (214) 871-3555. THE OFFERING Common Stock Offered by the Selling Stockholders.......... 1,000,000 shares Common Stock to be Outstanding after the Offering.................... 8,253,514 shares Use of Proceeds..................... The Company will not receive any of the proceeds from the sale of shares by the Selling Stockholders. See "Use of Proceeds." American Stock Exchange Symbol...... HOC Dividend Policy..................... The Company currently pays a quarterly dividend of $.10 per share of Common Stock outstanding. See "Price Range of Common Stock and Dividend Policy."
6 7 SUMMARY CONSOLIDATED FINANCIAL AND OPERATING DATA The summary consolidated financial data presented below for the five years ended July 31, 1994 have been derived from the Company's audited consolidated financial statements. The financial data for the nine months ended April 30, 1994 and at and for the nine months ended April 30, 1995 have been derived from the unaudited consolidated financial statements of the Company which, in the opinion of management, contain all adjustments, consisting only of normal, recurring adjustments, necessary to present fairly the Company's results of operations and financial position for such periods and at such dates. The consolidated results of operations for the nine months ended April 30, 1995 are not necessarily indicative of results to be expected for the full year or for future periods. The following summary consolidated financial and operating data should be read in conjunction with the more detailed financial and other information contained elsewhere herein. See "Selected Financial Data," "Management's Discussion and Analysis of Results of Operations and Financial Condition" and "Business."
NINE MONTHS ENDED APRIL 30, YEARS ENDED JULY 31, -------------------- ------------------------------------------------------------ 1995 1994 1994 1993 1992 1991 1990 -------- -------- -------- -------- -------- -------- -------- (DOLLARS IN THOUSANDS, EXCEPT PER SHARE AND OPERATING DATA) INCOME STATEMENT DATA: Revenues............................. $454,733 $400,141 $552,320 $630,621 $506,668 $489,333 $438,882 Income from operations............... 18,489 42,152 43,540 38,671 11,016 20,830 41,772 Interest expense, net................ 5,605 6,548 8,538 9,354 9,654 3,889 4,880 Income before cumulative effect of accounting change.................. 7,859 21,269 20,717 19,933 2,759 11,734 23,955 Cumulative effect of accounting change............................. 5,703 -- -- (958) -- -- -- Net income........................... 13,562 21,269 20,717 18,975 2,759 11,734 23,955 Income per common share: Before cumulative effect of accounting change................ $ .95 $ 2.58 $ 2.51 $ 2.42 $ .33 $ 1.42 $ 2.90 Cumulative effect of accounting change........................... .69 -- -- (.12) -- -- -- -------- -------- -------- -------- -------- -------- -------- Net income......................... $ 1.64 $ 2.58 $ 2.51 $ 2.30 $ .33 $ 1.42 $ 2.90 ======== ======== ======== ======== ======== ======== ======== OTHER FINANCIAL DATA: EBITDA(1)............................ $ 30,224 $ 50,203 $ 54,411 $ 54,015 $ 20,401 $ 29,289 $ 48,797 Net cash provided by operating activities......................... 26,733 27,882 27,684 38,737 961 27,907 33,643 Capital expenditures................. 10,606 18,505 22,521 20,120 22,317 53,899 13,889 Cash dividends per common share...... $ .30 $ .25 $ .35 $ .30 $ .45 $ .48 $ .40
APRIL 30, 1995 -------------- (IN THOUSANDS) BALANCE SHEET DATA: Working capital.................................................................................... $ 28,374 Total assets....................................................................................... 290,433 Long-term debt (less current maturities)........................................................... 68,832 Stockholders' equity............................................................................... 76,299
7 8
NINE MONTHS ENDED APRIL 30 YEARS ENDED JULY 31, ------------------ ------------------------------------------------------- 1995 1994 1994 1993 1992 1991 1990 ------- ------- ------- ------- ------- ------- ------- OPERATING DATA: Refinery production (BPD)(2)............... 67,900 63,300(3) 64,300(3) 65,300 55,200 44,800(3) 46,400 Crude charge (BPD)(4)...................... 65,159 59,404(3) 60,911(3) 62,115 51,723 43,838(3) 46,071 Refinery utilization (BPD)(5).............. 97.3% 88.7%(3) 90.9%(3) 92.7% 88.2% 93.3%(3) 98.0% Average per barrel: Net sales................................ $ 23.85 $ 22.63 $ 22.88 $ 25.43 $ 24.84 $ 29.79 $ 25.41 Raw materials costs(6)................... 19.01 16.13 16.99 20.10 20.41 24.61 19.76 ------- ------- ------- ------- ------- ------- ------- Gross margin............................. $ 4.84 $ 6.50 $ 5.89 $ 5.33 $ 4.43 $ 5.18 $ 5.65 ======= ======= ======= ======= ======= ======= ======= Product sales (percent of total sales volume)(7): Gasolines................................ 57.4% 54.9% 54.5% 52.0% 49.4% 46.6% 46.6% Diesel fuels............................. 19.4 20.7 20.1 23.6 21.1 20.1 18.7 Jet fuels................................ 11.3 11.4 11.7 10.4 13.2 18.2 20.5 Asphalt.................................. 7.3 8.6 9.4 9.8 10.8 8.9 8.1 LPG and other............................ 4.6 4.4 4.3 4.2 5.5 6.2 6.1 ------- ------- ------- ------- ------- ------- ------- Total.................................. 100.0% 100.0% 100.0% 100.0% 100.0% 100.0% 100.0% ======= ======= ======= ======= ======= ======= =======
- --------------- (1) EBITDA is defined as earnings before interest, taxes, depreciation and amortization and is presented herein because it is commonly used to evaluate a company's ability to service and/or to incur debt or to fund capital expenditures. EBITDA should not be considered in isolation or as a substitute for operating income, cash flows from operating activities and other consolidated income or cash flow data prepared in accordance with generally accepted accounting principles or as a measure of the Company's profitability or liquidity. (2) Barrels per calendar day of refined products produced from crude oil and other raw materials. (3) Refinery production, crude charge and utilization rates were reduced as a result of a scheduled four-week turnaround for major maintenance at the Navajo Refinery. (4) Barrels per day of crude oil processed. (5) Crude charge divided by crude capacity. (6) Includes cost of refined products purchased for resale. (7) Includes refined products purchased for resale representing 2.5%, 3.7%, 3.9%, 3.2%, 0.7%, 0.7% and 0.3%, respectively, of total sales volume for the periods shown in the table above. 8 9 RISK FACTORS Prospective purchasers of the shares of Common Stock offered hereby should consider carefully the following factors, as well as the other information set forth or incorporated by reference in this Prospectus. FLUCTUATIONS IN REFINING MARGINS The Company's operating results depend largely on the spread, or margin, between prices paid by the market for refined petroleum products and prices paid by the Company for crude oils and feedstocks. The Company's refining margins and operating results have fluctuated, and will continue to fluctuate, due to numerous factors, including changes in operating levels of other refineries in the Company's marketing areas and in other areas of the United States, changes in the differentials between sour and sweet crude oil prices on international and U.S. markets, changes in the level of imported refined products and variations in levels of demand for its principal products. Although an increase or decrease in the price of crude oil generally results in a corresponding increase or decrease in the price of refined products, changes in the prices of refined products generally lag behind upward and downward changes in crude oil prices. As a result, a rapid and significant increase in the market price for crude oil could have an adverse impact on refining margins. The Company's future results of operations will continue to be affected by these factors. Future margins, results of operations and earnings per share could also be affected by other factors beyond the Company's control, such as changes in, or the enactment of, environmental or other regulations, which could require substantial expenditures without necessarily increasing capacity or operating efficiency. See "Management's Discussion and Analysis of Results of Operations and Financial Condition" and "Business." DEPENDENCE ON NAVAJO REFINERY; INSURANCE The Company's performance depends primarily upon Navajo's results of operations. Prolonged downtime of the Navajo Refinery for scheduled maintenance turnarounds, unanticipated repairs or other reasons could materially and adversely affect the Company's operating results. The Company's operations (including its limited exploration and production activities) are subject to normal business hazards and risks. The Company maintains insurance for its operations, but there is no assurance that the Company will not incur losses beyond the limits, or outside the coverage, of its insurance. See "Business -- Insurance." UNCERTAINTIES RELATED TO CAPITAL IMPROVEMENT PROJECTS The Company intends to implement the capital improvement projects it has identified for enhancing the Navajo Refinery utilizing cash flows from operating activities. The Company's results of operations will be affected by future operating margins and other factors, some of which will be beyond its control. The Company's ability to implement the identified refinery enhancement projects will also be affected by other factors, some of which also will be beyond the Company's control. Among those factors will be the absence of unanticipated technical difficulties, fabrication delays or other occurrences, all of which could increase the cost, and delay the completion, of these projects. In addition, the identified refinery enhancement projects will require the Company to obtain certain governmental approvals, and there can be no assurance whether or when the Company will obtain those permits. Because of these uncertainties, the Company is unable to predict when these projects will be fully implemented or to provide any assurance that the anticipated benefits of these projects will be realized or, if realized, will not be offset by other factors affecting the Company's operations. In addition to the foregoing, management will have broad discretion in deciding whether to implement other capital improvement projects it is currently evaluating, and there can be no assurance that the Company will have sufficient sources of funds to implement any or all of its currently identified or other capital projects. COMPETITION; PIPELINE CONSTRAINTS The petroleum refining business is highly competitive. Among the Company's competitors are some of the world's largest integrated petroleum companies, which have their own crude oil supplies, distribution and marketing systems. In addition, Diamond Shamrock, Inc., an independent refiner and marketer, is building a 420-mile, ten-inch refined products pipeline from its McKee refinery near Dumas, Texas to El Paso, the 9 10 Company's largest market. Diamond Shamrock has announced that it expects to complete that pipeline, which will have an initial capacity of 25,000 BPD, in October 1995, and that it intends to use its pipeline to supply fuel to the El Paso, Arizona and northern Mexico markets. The Diamond Shamrock pipeline could substantially increase the supply of products in certain of the Company's principal markets. In addition, there is currently excess pipeline capacity from the West Coast into the Company's Arizona markets. There can be no assurance that West Coast refiners will not seek to increase shipments of refined products into the Company's markets or that other industry participants will not seek to deliver their products to the Company's markets through existing pipelines, new pipelines or otherwise. For example, in June 1995, an investor group announced that it is negotiating to purchase an existing crude oil pipeline running from West Texas to a refinery near Houston as part of the investor group's plan to reverse the line and extend it for use in transporting refined products from the Gulf Coast to El Paso. An increased supply of products in the Company's markets could adversely affect its sales volume and the prices it can obtain for its products. At times in the past, the common carrier pipelines used by the Company to serve the Arizona markets have been operated at or near their capacity. In addition, the common carrier pipeline used by the Company to serve the Albuquerque market currently is operating at or near capacity. As a result, the volume of refined products that the Company and other shippers have been able to deliver to these markets at times has been limited. In general, no assurances can be given that the Company will not experience future constraints on its ability to deliver its products through common carrier pipelines or that any existing constraints will not worsen. In particular, the flow of additional products into El Paso for shipment to Arizona, either as a result of the new Diamond Shamrock pipeline or otherwise, could result in the reoccurrence of such constraints. See "Business -- Navajo Refining Company -- Markets and Competition." SALES TO PRINCIPAL CUSTOMERS For the 1994 fiscal year, approximately 12% of the Company's revenues resulted from sales of jet fuel to the United States government and 11% were attributable to sales of gasoline to an affiliate of PEMEX, the government-owned energy company of Mexico. Sales to the United States government have been made pursuant to a series of one-year contracts and sales to PEMEX have been made under a contract that expires in mid-1997. The loss of either or both of these customers could have a material and adverse effect on the Company's results of operations. See "Business -- Navajo Refining Company -- Principal Products and Customers." ENVIRONMENTAL REGULATION The Company's operations are subject to federal, state and local laws and regulations governing, among other things, emissions to air, discharges to water, and transportation, treatment and disposal of waste and other materials. The Company is and has been the subject of various state, federal and private proceedings relating to environmental regulations and conditions, including a currently pending proceeding brought by the United States Department of Justice (the "DOJ") on behalf of the Environmental Protection Agency (the "EPA") alleging ongoing violations of the Resource Conservation and Recovery Act ("RCRA") at the Navajo Refinery. The Company believes that it is in the final stages of negotiating a settlement of this litigation with the DOJ and the EPA, which, if consummated, could involve expenditures by the Company of approximately $3 million to $4 million to construct a new wastewater management system and to close existing wastewater evaporation ponds. The Company also expects that the settlement will provide for the payment of a civil penalty of less than $2 million. There can be no assurance, however, that the Company and the government will settle the outstanding litigation or that, if not settled, the final resolution of that suit would not have a material adverse effect on the Company and its results of operations or financial condition. While the specifics cannot be presently determined, new laws or regulations or changes in existing laws or regulations could require the Company to make significant site or operational modifications, which could involve substantial expenditures or the reduction or suspension of certain operations. See "Business -- Regulation." 10 11 LIMITED LIQUIDITY OF COMMON STOCK; SHARES ELIGIBLE FOR FUTURE SALE Although the Common Stock is listed on the American Stock Exchange, trading volume has frequently been low over the past several years. Approximately 45% of the outstanding shares of Common Stock is held by or for the benefit of two families, which have been significant stockholders of the Company for over 30 years. Approximately 15% of the outstanding shares of Common Stock is held by the Company's Employee Stock Ownership Plan (the "ESOP"). Immediately after giving effect to the Offering, the two principal stockholder families, which are the Selling Stockholders in the Offering, will beneficially own, in the aggregate, approximately 33% of the outstanding Common Stock and the ESOP will own approximately 15% of the outstanding Common Stock. There can be no assurance that the consummation of the Offering will result in greater trading volume in the Common Stock. See "Price Range of Common Stock and Dividend Policy" and "Selling Stockholders." One hundred-eighty days after the date of this Prospectus, certain contractual restrictions agreed to by the stockholder families (see "Underwriting") will expire, and 2,698,167 shares of Common Stock held by such stockholders (representing approximately 33% of the total shares of Common Stock outstanding subsequent to the Offering) will be eligible for sale in the open market, pursuant to Rule 144 or otherwise. Sales of substantial amounts of Common Stock, or the perception that such sales could occur, could adversely affect prevailing market prices for the Common Stock. 11 12 USE OF PROCEEDS The Company will not receive any portion of the net proceeds from the sale of the shares of Common Stock by the Selling Stockholders. CAPITAL IMPROVEMENT PROJECTS IDENTIFIED REFINERY ENHANCEMENT PROJECTS As part of its efforts to improve production efficiencies, management currently intends to enhance the Navajo Refinery by upgrading the FCC and alkylation units, constructing an isomerization unit and installing a new SHP unit. These projects are intended to improve the Navajo Refinery's ability to produce a greater proportion of higher yielding products, principally "premium" (high octane) gasolines, and to enhance management's flexibility to choose among different types of crude oils and other raw materials in response to changing prices of supplies. The Company currently estimates that the cost of these projects will be approximately $15 million and expects to implement them over an 18-month period utilizing cash flows from operating activities. The Company's results of operations will be affected by future operating margins and other factors, some of which will be beyond its control. The modified FCC unit is expected to permit the refining of heavier feedstocks than are currently processed, which would enhance the Company's ability to take advantage of price differentials between sweet and sour crude oils. Similarly, the isomerization unit is expected to provide the Company with the ability to upgrade additional quantities of lower priced natural gasoline into finished gasoline. It is anticipated that the SHP unit and the upgraded alkylation unit will increase the refinery's production capacity for alkylate, a high octane gasoline blendstock, which also would contribute to the refinery's improved ability to produce premium unleaded gasolines and to upgrade natural gasoline into a refined product. Consequently, the Company expects that the enhancements to the Navajo Refinery will provide management with additional flexibility in managing the refinery's crude oil and other raw materials supplies. Further, based on industry studies concerning new environmental regulations promulgated by the California Air Resources Board and scheduled to go into effect in California in 1996, it appears that California refiners may require increased supplies of alkylates to produce the cleaner burning gasolines called for by the new regulations. In that event, the Navajo Refinery's increased production of alkylate could be made available for sale to California refineries. The Company expects to commence its identified refinery enhancement projects promptly. However, management intends to bring the new and upgraded equipment on-line in a manner that will minimize disruption to the Navajo Refinery's operations. Consequently, management does not expect to make the FCC modifications until the scheduled fall 1996 maintenance turnaround of the refinery. OTHER PROJECTS UNDER CONSIDERATION The Company is currently evaluating certain other enhancements and additions to the Navajo Refinery and the related supply and distribution systems to better position it to respond to competitive pressures and to meet possible increases in demand for refined products. Future capital projects that are being considered include (i) the redistribution of process activities between the Lovington and Artesia facilities in order to realize potential operating and transportation cost savings, (ii) other upgrades to improve the efficiency of the Navajo Refinery, (iii) modifications to increase product pipeline distribution capacity and (iv) product pipeline reconditioning and construction to facilitate entry into new markets. To the extent available, cash flows from operating activities could be used to finance the cost of these projects, although the Company may require additional funds if a decision were made to implement some or all of these projects. There can be no assurance that the Company will have sufficient sources of funds to implement any or all of these other capital projects. 12 13 CAPITALIZATION The following table sets forth the unaudited consolidated capitalization of the Company at April 30, 1995.
(DOLLARS IN THOUSANDS) ---------------------- Current maturities of long-term debt...................................... $ 5,608 Long-term debt, less current maturities................................... 68,832 Stockholders' equity: Preferred stock, par value $1.00 per share; 1,000,000 shares authorized; none issued and outstanding.......................................... -- Common stock, par value $.01 per share; 20,000,000 shares authorized; 8,650,282 shares issued and outstanding; 10,150,282 shares issued and outstanding, as adjusted............................................. 87 Additional capital...................................................... 6,132 Retained earnings....................................................... 71,059 ----------- 77,278 Common stock held in treasury, at cost; 396,768 shares.................. (569) Deferred charge -- amount due from ESOP................................. (410) ----------- Total stockholders' equity...................................... 76,299 ----------- Total capitalization............................................ $150,739 ===========
13 14 PRICE RANGE OF COMMON STOCK AND DIVIDEND POLICY The Common Stock is traded on the American Stock Exchange under the symbol "HOC". The following table sets forth the range of the daily high and low sale prices per share of Common Stock, as reported on the American Stock Exchange, and dividends paid per share of Common Stock for the periods indicated:
FISCAL YEARS ENDED JULY 31, HIGH LOW DIVIDENDS ---------------------------------------------------------- ---- ---- --------- 1993 First Quarter........................................... $25 $23 $.075 Second Quarter.......................................... 30 7/8 23 7/8 .075 Third Quarter........................................... 29 3/8 25 7/8 .075 Fourth Quarter.......................................... 30 1/2 26 3/8 .075 1994 First Quarter........................................... 30 26 5/8 .075 Second Quarter.......................................... 30 25 3/8 .075 Third Quarter........................................... 30 1/2 27 1/8 .10 Fourth Quarter.......................................... 33 3/8 28 1/4 .10 1995 First Quarter........................................... 28 1/2 23 3/4 .10 Second Quarter.......................................... 26 1/2 24 .10 Third Quarter........................................... 26 3/4 23 .10 Fourth Quarter (through June 27, 1995).................. 28 1/2 23 1/8 .10
As of May 31, 1995, the Company had approximately 2,100 stockholders of record. The Company, which currently pays a quarterly dividend of $.10 per share of Common Stock outstanding, considers the declaration of dividends on a quarterly basis. On June 9, 1995, the Company's Board of Directors declared a regular quarterly dividend in the amount of $.10 per share payable on July 7, 1995. The Company's ability to pay future dividends depends on its future earnings and capital requirements, and on its financial condition and other factors. The Company's senior notes (the "Senior Notes") and its revolving credit agreement (the "Credit Agreement") could limit the Company's ability to pay dividends under certain circumstances. See Note 6 to the Consolidated Financial Statements for the year ended July 31, 1994 included elsewhere herein. 14 15 SELECTED FINANCIAL DATA The selected financial data presented below for the five years ended July 31, 1994 have been derived from the Company's audited consolidated financial statements. The selected financial data at and for the nine months ended April 30, 1994 and 1995 have been derived from the unaudited consolidated financial statements of the Company which, in the opinion of management, contain all adjustments, consisting only of normal, recurring adjustments, necessary to present fairly the Company's results of operations and financial position for such periods and at such dates. The consolidated results of operations for the nine months ended April 30, 1995 are not necessarily indicative of the results to be expected for the full year or for future periods. The selected financial data presented below should be read in conjunction with the Consolidated Financial Statements of the Company and the related notes thereto included elsewhere in this Prospectus.
NINE MONTHS ENDED APRIL 30, YEARS ENDED JULY 31, ----------------------- ----------------------------------------------------------------- 1995 1994 1994 1993 1992 1991 1990 --------- --------- --------- --------- --------- --------- --------- (DOLLARS IN THOUSANDS, EXCEPT PER SHARE AMOUNTS) INCOME STATEMENT DATA: Revenues....................... $ 454,733 $ 400,141 $ 552,320 $ 630,621 $ 506,668 $ 489,333 $ 438,882 Costs and expenses: Cost of sales................ 412,322 337,921 480,916 565,638 474,151 448,356 377,853 General and administrative... 9,629 9,153 12,369 11,951 9,263 9,200 9,699 Depreciation, depletion and amortization............... 11,735 8,051 10,871 11,344 10,085 6,984 6,515 Exploration expenses, including dry holes........ 2,451 2,706 4,441 2,867 2,005 3,834 2,576 Miscellaneous................ 107 158 183 150 148 129 467 --------- --------- --------- --------- --------- --------- --------- 436,244 357,989 508,780 591,950 495,652 468,503 397,110 --------- --------- --------- --------- --------- --------- --------- Income from operations......... 18,489 42,152 43,540 38,671 11,016 20,830 41,772 Other income (expense) Interest income.............. 732 254 447 169 432 419 517 Interest expense............. (6,337) (6,802) (8,985) (9,523) (10,086) (4,308) (5,397) Other........................ -- -- -- 4,000 (700) 1,475 510 --------- --------- --------- --------- --------- --------- --------- (5,605) (6,548) (8,538) (5,354) (10,354) (2,414) (4,370) --------- --------- --------- --------- --------- --------- --------- Income before income taxes and cumulative effect of accounting change............ 12,884 35,604 35,002 33,317 662 18,416 37,402 Income tax provision (benefit).................... 5,025 14,335 14,285 13,384 (2,097) 6,682 13,447 --------- --------- --------- --------- --------- --------- --------- Income before cumulative effect of accounting change......... 7,859 21,269 20,717 19,933 2,759 11,734 23,955 Cumulative effect of accounting change....................... 5,703 -- -- (958) -- -- -- --------- --------- --------- --------- --------- --------- --------- Net income..................... $ 13,562 $ 21,269 $ 20,717 $ 18,975 $ 2,759 $ 11,734 $ 23,955 ========= ========= ========= ========= ========= ========= ========= Income per common share: Income before cumulative effect of accounting change..................... $ .95 $ 2.58 $ 2.51 $ 2.42 $ .33 $ 1.42 $ 2.90 Cumulative effect of accounting change.......... .69 -- -- (.12) -- -- -- --------- --------- --------- --------- --------- --------- --------- Net income................... $ 1.64 $ 2.58 $ 2.51 $ 2.30 $ .33 $ 1.42 $ 2.90 ========= ========= ========= ========= ========= ========= =========
15 16
NINE MONTHS ENDED APRIL 30, YEARS ENDED JULY 31, ----------------------- ----------------------------------------------------------------- 1995 1994 1994 1993 1992 1991 1990 --------- --------- --------- --------- --------- --------- --------- (DOLLARS IN THOUSANDS, EXCEPT PER SHARE AND OPERATING DATA) OTHER FINANCIAL DATA: EBITDA(1)...................... $ 30,224 $ 50,203 $ 54,411 $ 54,015 $ 20,401 $ 29,289 $ 48,797 Net cash provided by operating activities................... 26,733 27,882 27,684 38,737 961 27,907 33,643 Capital expenditures........... 10,606 18,505 22,521 20,120 22,317 53,899 13,889 Cash dividends per common share........................ $ .30 $ .25 $ .35 $ .30 $ .45 $ .48 $ .40 Average number of shares of common stock outstanding..... 8,253,514 8,253,514 8,253,514 8,253,514 8,253,514 8,253,514 8,253,514 REFINERY OPERATING DATA: Refinery production (BPD)(2)... 67,900 63,300(3) 64,300(3) 65,300 55,200 44,800(3) 46,400 Crude charge (BPD)(4).......... 65,139 59,404(3) 60,911(3) 62,115 51,723 43,838(3) 46,071 Refinery utilization (BPD)(5)..................... 97.3% 88.7%(3) 90.9%(3) 92.7% 88.2% 93.3%(3) 98.0% Average per barrel: Net sales.................... $ 23.85 $ 22.63 $ 22.88 $ 25.43 $ 24.84 $ 29.79 $ 25.41 Raw materials costs(6)....... 19.01 16.13 16.99 20.10 20.41 24.61 19.76 --------- --------- --------- --------- --------- --------- --------- Gross margin................. $ 4.84 $ 6.50 $ 5.89 $ 5.33 $ 4.43 $ 5.18 $ 5.65 ========= ========= ========= ========= ========= ========= ========= Product sales (percent of total sales volume)(7): Gasolines.................... 57.4% 54.9% 54.5% 52.0% 49.4% 46.6% 46.6% Diesel fuels................. 19.4 20.7 20.1 23.6 21.1 20.1 18.7 Jet fuels.................... 11.3 11.4 11.7 10.4 13.2 18.2 20.5 Asphalt...................... 7.3 8.6 9.4 9.8 10.8 8.9 8.1 LPG and other................ 4.6 4.4 4.3 4.2 5.5 6.2 6.1 --------- --------- --------- --------- --------- --------- --------- Total.................. 100.0% 100.0% 100.0% 100.0% 100.0% 100.0% 100.0% ========= ========= ========= ========= ========= ========= =========
APRIL 30, JULY 31, ----------------------- ----------------------------------------------------------------- 1995 1994 1994 1993 1992 1991 1990 --------- --------- --------- --------- --------- --------- --------- (DOLLARS IN THOUSANDS) BALANCE SHEET DATA: Working capital................ $ 28,374 $ 23,568 $ 18,236 $ 12,145 $ 5,031 $ 18,658 $ 11,608 Total assets................... 290,433 266,390 281,814 249,807 245,462 212,095 149,503 Long-term debt (less current maturities).................. 68,832 74,440 68,840 74,448 80,056 80,164 34,136 Stockholders' equity........... 76,299 66,134 64,772 46,478 29,505 29,811 21,371
- --------------- (1) EBITDA is defined as earnings before interest, taxes, depreciation and amortization and is presented herein because it is commonly used to evaluate a company's ability to service and/or to incur debt or to fund capital expenditures. EBITDA should not be considered in isolation or as a substitute for operating income, cash flows from operating activities and other consolidated income or cash flow data prepared in accordance with generally accepted accounting principles or as a measure of the Company's profitability or liquidity. (2) Barrels per calendar day of refined products produced from crude oil and other raw materials. (3) Refinery production, crude charge and utilization rates were reduced as a result of a scheduled four-week turnaround for major maintenance at the Navajo Refinery. (4) Barrels per day of crude oil processed. (5) Crude charge divided by crude capacity. (6) Includes cost of refined products purchased for resale. (7) Includes refined products purchased for resale representing 2.5%, 3.7%, 3.9%, 3.2%, 0.7%, 0.7% and 0.3%, respectively, of the total sales volume for the periods shown in the table above. 16 17 MANAGEMENT'S DISCUSSION AND ANALYSIS OF RESULTS OF OPERATIONS AND FINANCIAL CONDITION OVERVIEW The Company's operating results depend largely on the spread, or margin, between prices paid by the market for refined petroleum products and prices paid by the Company for crude oils and feedstocks. The Company's refining margins and operating results have fluctuated, and will continue to fluctuate, due to numerous factors, including changes in operating levels of other refineries in the Company's marketing areas and in other areas of the United States, changes in the differentials between sour and sweet crude oil prices on international and U.S. markets, changes in the level of imported refined products and variations in levels of demand for its principal products. Although an increase or decrease in the price of crude oil generally results in a corresponding increase or decrease in the price of refined products, changes in the prices of refined products generally lag behind upward and downward changes in crude oil prices. As a result, a rapid and significant increase in the market price for crude oil could have an adverse impact on refining margins. The Company's future results of operations will continue to be affected by these factors. Future margins, results of operations and earnings per share could also be affected by other factors beyond the Company's control, such as changes in, or the enactment of, environmental or other regulations, which could require substantial expenditures without necessarily increasing capacity or operating efficiency. The Company's results of operations experience some seasonal fluctuations, with demand for gasoline and asphalt products historically being stronger from March through October, which are the key "driving" and road construction months, than during the rest of the year. In addition, the Company's refineries are subject to preventive maintenance turnarounds scheduled at two- or three-year intervals, during which all or a portion of the facilities are shut down. As a result, the Company's operating results during the periods and full fiscal years when turnarounds occur typically will be below the Company's results for the comparable prior year periods. In addition, in part because the Navajo and Montana Refineries serve markets with different supply and demand relationships, the refineries' operating results do not always increase or decrease in tandem. Consequently, there have been periods (such as fiscal 1994 and 1993) when MRC's results of operations have contributed more to the Company's overall results of operations than management ordinarily would expect given the relative size of the Navajo and Montana Refineries. RESULTS OF OPERATIONS Nine Months ended April 30, 1995 Versus Nine Months ended April 30, 1994 For the nine months ended April 30, 1995, net income was $13.6 million, which included a $5.7 million contribution in the first quarter from the cumulative effect of a change in accounting for turnarounds relating to prior periods, compared to $21.3 million for the same period of fiscal 1994. Effective August 1, 1994, the Company changed its method of accounting for turnaround costs. Turnarounds consist of preventive maintenance on major processing units as well as the shutdown and restart of all units, and generally are scheduled at two- to three-year intervals. Previously, the Company estimated the costs of the next scheduled turnaround and ratably accrued the related expenses prior to the actual turnaround. To provide for a better matching of turnaround costs with revenues, the Company changed its accounting method for turnaround costs to one that results in the amortization of costs incurred over the period until the next scheduled turnaround. The amortization of turnaround costs is recorded in depreciation, depletion and amortization expense, whereas previously the expenses accrued prior to the turnaround were recorded in cost of sales as an operating expense. The increase in the current year in depreciation expense is primarily the result of this change in accounting. The cumulative effect of this accounting change was to increase net income in the current year by $5.7 million. Excluding the cumulative effect of the accounting change, the new method of accounting for turnaround costs increased net income for the first nine months of fiscal 1995 by $1.0 million to $7.9 million. If the accounting change for turnaround costs had been retroactively applied, pro forma net income for the nine months ended April 30, 1994 would have increased by $1.2 million to $22.4 million and pro forma net income for the full 1994 fiscal year would have increased by $1.3 million to $22.0 million. 17 18 Excluding the effects of the change in accounting for turnarounds, the $13.4 million decrease in net income for the first nine months of 1995 compared to the prior year period is due primarily to a 26% reduction in gross margins per barrel, offset partially by an 8% increase in volumes sold. Gross margins for the current year were less than in the comparable prior year period because crude oil costs per barrel increased 18% over the prior year, while product prices per barrel increased only 5%. Gross margins per barrel at the Montana Refinery were 34% below the comparable prior year period because product prices per barrel increased 1% over the prior year levels while crude oil costs per barrel increased 27%; gross margins were weakest in the latter part of the second quarter and the early part of the third quarter of 1995. In addition, gross margins per barrel at the Navajo Refinery in the third quarter of 1995 were approximately 32% below the comparable prior year period, which was the primary reason for the $400,000 loss for the third quarter. Revenues for the nine months ended April 30, 1995 were 14% higher than in the comparable prior year period due to an 8% increase in sales volumes in the current year period and 5% higher product prices per barrel in the first nine months of 1995 compared to the 1994 period. The prior year's sales volumes were adversely affected by the scheduled maintenance turnaround at the Navajo Refinery from September to November 1993. 1994 Versus 1993 Net income for the year ended July 31, 1994 was $20.7 million compared to $19.9 million before an accounting change in the 1993 fiscal year. In the 1993 fiscal year, the Company adopted Statement of Financial Accounting Standards No. 109, "Accounting for Income Taxes" ("SFAS 109"), which amended the accounting for income taxes from the deferral method to the liability method. The cumulative effect of this change in accounting was to decrease net income by $1.0 million to $19.0 million for the year ended July 31, 1993. Other than the cumulative effect of the adjustment, the effect of the change on income for the year ended July 31, 1993 was not material. While gross margins per barrel for the 1994 fiscal year as a whole improved 11% over the levels of the prior year, the 1994 year's margins per barrel were adversely affected by Navajo's refined product margins per barrel in the fourth quarter of 1994, which decreased 43% from the same period during 1993 because product prices per barrel fell 9% in the fourth quarter of 1994 while crude oil costs per barrel rose 3% in the same period. MRC had a third consecutive record earnings year in fiscal 1994 because its gross margins were positively affected by favorable prices for crude oil and other feedstocks. Notwithstanding the Company's higher gross margins, as a whole, for 1994 compared to 1993, net sales for the 1994 fiscal year decreased 13% from the prior year's levels as the result of a 10% decrease in product prices per barrel and a 3% decline in sales volume for the year caused primarily by a scheduled major maintenance turnaround of the Navajo Refinery. Under the prior accounting method, a charge of $2.9 million was recorded in the fourth quarter of fiscal 1993 to reflect an increase in the estimate for the costs to be incurred in the turnaround, and an additional $1.5 million in excess of the revised accrual at July 31, 1993 was included as an expense with respect to the scheduled turnaround in the 1994 year's second quarter. Increases in other operating expense and in exploration expenses, including dry holes, further reduced income in 1994. Pre-tax income in 1993 was improved by $4 million relating to the settlement of litigation with a common carrier pipeline and was reduced by a $2 million charge relating to an enforcement action brought by the DOJ alleging that Navajo, beginning in September 1990 and continuing until the present, violated and continues to violate the RCRA and implementing regulations by treating, storing and disposing of certain hazardous wastes without required authorization and without compliance with regulatory requirements. See "Financial Condition" below. 1993 Versus 1992 Net income for the year ended July 31, 1993 was $19.9 million before a $1.0 million accounting change related to the adoption of SFAS 109 as discussed above, compared to $2.8 million in the prior year. Net income for the year ended July 31, 1993 improved substantially over the prior year due to 20% and 22% increases in gross margins per barrel and sales volumes, respectively. The increase in sales volume over the prior year resulted from higher throughputs made possible by the refinery expansion completed in 18 19 December 1991 and the alleviation of product pipeline distribution constraints in October 1992. Gross margins and sales volumes for the 1993 fiscal year also may have been favorably affected by a temporary suspension of production during most of the year by a refinery in the Company's principal market area. In addition, MRC experienced a second consecutive record earnings year in fiscal 1993. Profitability in fiscal 1993 was reduced due to increases in operating expenses, principally resulting from a charge taken in the fourth quarter of $2.9 million to increase the estimate for the planned fall 1993 major maintenance turnaround and increases in general and administrative expense and depreciation, depletion and amortization expense, primarily attributable to the refinery expansion. Net income in the fourth quarter of the 1993 fiscal year was affected by pretax income of $4 million relating to a settlement of litigation with a common carrier pipeline company and the $2 million pre-tax charge established in connection with the DOJ litigation. Net income in the fourth quarter of fiscal 1992 was improved by the elimination, as a consequence of the Company's acquisition of the remaining interest in MRC, of a $2.6 million liability for deferred taxes that had been reflected on the Company's financial statements. FINANCIAL CONDITION Cash flows from operations during the nine months ended April 30, 1995 exceeded capital expenditures and dividends paid, resulting in a net increase in cash and cash equivalents of $13.6 million. Cash flows from operations for fiscal 1994 were slightly less than capital expenditures, debt payments and dividends paid, resulting in a net decrease in cash and cash equivalents of $3.3 million. Working capital increased during the first nine months of 1995 by $10.1 million to $28.4 million at April 30, 1995. The Company's long-term debt represented 49.4% of total capitalization at April 30, 1995 compared to 53.5% at July 31, 1994. At April 30, 1995, the Company had $25 million of borrowing capacity under the Credit Agreement, which is available for short term working capital needs. The Company believes that these sources of funds, together with future cash flows from operations, should provide sufficient resources, financial strength and flexibility for the Company to satisfy its liquidity needs, capital requirements (including requirements related to the identified refinery enhancement projects for the Navajo Refinery) and debt service obligations and to permit the payment of dividends for the foreseeable future. Net cash provided by operating activities amounted to $26.7 million in the first nine months of fiscal 1995, compared to $27.9 million in the same period of the prior year. The principal reason for the slight decrease in cash provided from operations was the reduction in income before the accounting change, which was almost offset by changes in working capital accounts. The change in the method of accounting for turnaround costs had no effect on cash provided from operations. Net cash provided by operating activities amounted to $27.7 million in fiscal 1994, compared to $38.7 million in fiscal 1993 and $1.0 million in fiscal 1992. The primary reason for the differences in cash provided from operations during the three years ended July 31, 1994 was differences in earnings, which were $20.7 million in fiscal 1994, $19.0 million in fiscal 1993 and $2.8 million in fiscal 1992. Additionally, significant amounts of funds were required in both fiscal 1994 and fiscal 1992 to maintain working capital accounts compared to the 1993 fiscal year. Cash flows used for investing activities (consisting solely of capital expenditures) were $10.6 million in the first nine months of fiscal 1995, compared to $18.5 million in the same period of the prior year. Cash flows used for investing activities totalled $65.7 million over the last three full fiscal years, $22.5 million in 1994, $20.1 million in 1993 and $23.1 million in 1992, principally for capital expenditures. The expenditures in 1992 were primarily for the final phases of the expansion of the Navajo Refinery's crude capacity from 40,000 to 60,000 BPD. This expansion included the installation of a new continuous catalytic regeneration reformer, the modification of the fluid catalytic cracker, the expansion of the naphtha desulfurizer and the installation of a new sulphur plant and alkylation unit. In fiscal 1993 and 1994, most of the funds expended were for refinery projects including diesel desulfurization units at the Navajo and Montana Refineries in order to meet the October 1993 requirements for lower sulphur content in diesel fuel. The Navajo Refinery unit was completed in August 1993 and the Montana Refinery unit was completed in December 1993. The Company currently plans to use approximately $15 million of its future operating cash flow to pay for the identified capital improvement projects to enhance the Navajo Refinery described under "Capital 19 20 Improvement Projects -- Identified Refinery Enhancement Projects." The Company's results of operations will be affected by future operating margins and other factors, some of which will be beyond its control. There can be no assurance that the Company will have sufficient sources of funds to implement any or all of these projects. Excluding the capital improvement projects described under "Capital Improvement Projects," the Company has a $15 million capital budget for fiscal 1995, of which $11 million is for refinery projects with the remaining $4 million for oil and gas exploration. Although there can be no assurances, management considers the planned maintenance expenditures for 1995 of approximately $8 million to be indicative of the level of capital spending that will be necessary to maintain the Company's operations in the future. The majority of the oil and gas budget will be used to fund the anticipated costs of completion of production facilities for two offshore properties in which the Company has an interest. Although the Company's capital expenditures budget contemplates capitalizable costs associated with compliance with environmental regulations, the regulations implementing recent amendments to the Clean Air Act could have a substantial impact on the Company's future capital spending requirements. Final regulations implementing these amendments have not yet been promulgated; therefore the costs of complying with these regulations are not yet determinable by the Company. In addition, the Company is unable to predict the impact that new environmental rules and regulations or changes in interpretations of existing laws and regulations might have on its capital spending needs. Cash flows used for financing activities amounted to $2.5 million in the first nine months of fiscal 1995, compared to $2.1 million in the same period of the prior year; substantially all these amounts were for dividends. The next principal payment of $5.6 million on the Company's Senior Notes is due in June 1995. Cash flows used for financing activities amounted to $8.5 million and $13.4 million in fiscal 1994 and 1993, respectively, compared to cash flows provided by financing activities of $6.3 million in fiscal 1992. Financing activities over the last three years included the renewal of the Company's Credit Agreement in July 1993, which provides for a total facility of $100 million, the full amount of which may be used to support letters of credit and $25 million of which may be used for direct borrowings for short-term working capital needs. The Company had $10.5 million of borrowings outstanding under its Credit Agreement as of July 31, 1992, the full amount of which was repaid during fiscal 1993. The Company's Credit Agreement will expire August 1, 1995; however, the Company expects to renew the Credit Agreement on substantially the same terms. The Company's first principal payment of $5.6 million on the Senior Notes was made in June 1994. See Note 6 to the Consolidated Financial Statements for the year ended July 31, 1994 included elsewhere herein for a summary of the terms of the Senior Notes and the Credit Agreement, which could restrict the Company's ability to pay dividends under certain circumstances. Diamond Shamrock, Inc., an independent refiner and marketer, is building a 420-mile, ten-inch refined products pipeline from its McKee refinery near Dumas, Texas to El Paso, the Company's largest market. Diamond Shamrock has announced that it expects to complete that pipeline, which will have an initial capacity of 25,000 BPD, in October 1995, and that it intends to use its pipeline to supply fuel to the El Paso, Arizona and northern Mexico markets. The Diamond Shamrock pipeline could substantially increase the supply of products in the Company's principal markets. In addition, in June 1995, an investor group announced that it is negotiating to purchase an existing crude oil pipeline running from West Texas to a refinery near Houston as part of the investor group's plan to reverse the line and extend it for use in transporting refined products from the Gulf Coast to El Paso. At times in the past, the common carrier pipelines used by the Company to serve the Tucson and Phoenix markets have been operated at or near their capacity. In addition, the common carrier pipeline used by the Company to serve the Albuquerque market currently is operating at or near capacity. As a result, the volume of refined products that the Company and other shippers have been able to deliver to these markets at times has been limited. In general, there is no assurance that the Company will not experience future constraints on its ability to deliver its products through common carrier pipelines or that any existing constraints will not worsen. In particular, the flow of additional product into El Paso for shipment to Arizona, either as a result of the new Diamond Shamrock pipeline or otherwise, could result in the reoccurrence of such constraints. See "Business -- Navajo Refining Company -- Markets and Competition." In July 1993, the DOJ, on behalf of the EPA, filed suit against Navajo alleging that, beginning in September 1990 and continuing through the present, Navajo has violated and continues to violate RCRA and 20 21 implementing regulations of the EPA by treating, storing and disposing of certain hazardous wastes without compliance with regulatory requirements. The Company believes that the parties are in the final stage of negotiating a resolution of the litigation. If settled as anticipated, the Company would close the existing evaporation ponds of its wastewater management system at a cost believed to be substantially less than $1 million. The settlement also contemplates that the Company would implement one of several alternatives to the existing wastewater treatment system. Depending upon which approach were utilized, the Company could incur total costs of approximately $3 million over the next several years. The costs to implement an alternative wastewater treatment system would be capitalized and amortized over the future useful life of the resulting asset in accordance with generally accepted accounting principles. The settlement with the DOJ also is expected to involve the payment of a civil penalty of less than $2 million. In fiscal 1993, the Company recorded a $2 million reserve for the litigation. See "Risk Factors -- Environmental Regulation." 21 22 BUSINESS OVERVIEW The Company is an independent refiner of petroleum and petroleum derivatives and produces high value light products such as gasoline, diesel fuel and jet fuel for sale primarily in the southwestern United States and northern Mexico. The Company owns a high-conversion petroleum refinery in Artesia, New Mexico, which it operates in conjunction with crude, vacuum distillation and other facilities situated 65 miles away in Lovington, New Mexico. The Navajo Refinery has a crude capacity of 60,000 BPD and can process a variety of high sulphur sour crude oils. For the last three fiscal years, sour crude oils have represented approximately 85% of the crude oils processed by the Navajo Refinery. The Navajo Refinery's processing capabilities enable management to vary its crude supply mix to take advantage of changes in raw materials prices and to respond to fluctuations in the availability of crude oil supplies. The Navajo Refinery converts approximately 86% of its raw materials throughput into high value light products. For fiscal 1994, including barrels purchased for resale, gasoline, diesel fuel and jet fuel represented 56.5%, 19.7% and 11.1%, respectively, of Navajo's sales volume. For the last three fiscal years, excluding downtime for scheduled maintenance and turnarounds, the Navajo Refinery has operated at an average annual crude capacity utilization rate of approximately 93%. The Artesia facility is located on a 300-acre site and has fully integrated crude, FCC, vacuum distillation, alkylation, hydrodesulfurization and reforming units, and approximately 1.5 million barrels of feedstock and product tank storage. The Lovington facility is operated as an integrated component of the Navajo Refinery and refines crude oil into intermediate products, which are transported, primarily via a Company-owned pipeline, to the Artesia facility for further processing. Navajo's assets also include a 500-mile crude oil gathering pipeline system, 30 crude oil and product tank trucks, three refined products pipelines and product storage at terminals in Tucson, Albuquerque, Artesia and El Paso in which the Company has 50% or greater interests. The Company also owns a 7,000 BPD petroleum refinery near Great Falls, Montana, which can process a range of crude oils and which serves primarily the State of Montana. For fiscal 1994, including barrels purchased for resale, gasoline, diesel fuel, asphalt and jet fuels, represented 38.6%, 24.3%, 18.6% and 15.7% of MRC's sales volume. For the last three fiscal years, excluding downtime for scheduled maintenance and turnarounds, the Montana Refinery has operated at an average annual crude capacity utilization rate of approximately 94%. In addition to its refining operations, the Company also conducts a small-scale oil and gas exploration and production program. BUSINESS STRENGTHS Despite fluctuating industry conditions, the Company, which was incorporated in 1947 and acquired the Navajo Refinery in 1969, has generated positive net income and cash flow from operations for each of the past 24 years. The Company had net income and cash from operating activities of $24.0 million and $33.6 million, respectively, for fiscal 1990, $11.7 million and $27.9 million for fiscal 1991, $2.8 million and $1.0 million for fiscal 1992, $19.0 million and $38.7 million for fiscal 1993, and $20.7 million and $27.7 million for fiscal 1994. The Company believes that it has certain business strengths that have contributed to its history of profitable operations. Among those strengths are the following: - Geographic location/attractive markets. The Navajo Refinery primarily serves the growing southwestern United States market, including El Paso, Albuquerque, Phoenix and Tucson, which generally has favorable supply and demand characteristics compared to Gulf Coast markets, and the northern Mexico market, which is expected to experience demand growth over the next several years. According to data compiled by the United States Bureau of the Census, from April 1, 1990 to July 1, 1993, the population of the Navajo Refinery's principal market area in the U.S. (Arizona, New Mexico and El Paso) grew at a compound annual rate of 2.2%, compared to a nationwide compound annual growth rate of 1.1% during that period. From April 1, 1980 to July 1, 1993, this area grew at a compound annual rate of 2.5%, compared to a nationwide rate of 1.0%. The Montana Refinery serves primarily the 22 23 State of Montana, which also historically has had relatively favorable supply and demand characteristics. - High conversion refinery. The Navajo Refinery converts approximately 86% of its raw materials throughput into high value light products from a variety of sour crudes and can vary the refined products it produces to respond to fluctuations in demand. The Navajo Refinery's processing facilities also enable management to vary the refinery's crude supply mix to take advantage of changes in raw materials prices and to respond to fluctuations in the availability of crude oil supplies. For the last three fiscal years, sour crude oils have represented approximately 85% of the crude oils processed by the Navajo Refinery. - Raw material supply. Located on the northwestern shelf of the Permian Basin, the Navajo Refinery has direct access to a historically reliable crude oil supply, which is transported to the refinery primarily through a 500-mile, Company-owned crude oil pipeline gathering system and by crude oil tank trucks. The Company's crude oil pipelines connect to tankage facilities in New Mexico and Texas, and are connected to, or are located in proximity to, a number of common carrier crude oil pipelines. The Montana Refinery obtains most of its crude oil via a 93-mile, Company-owned pipeline which runs from near the Canadian border. - Distribution logistics. The Company distributes refined products from the Navajo Refinery to its principal markets primarily through (i) a Company-owned pipeline extending from Artesia to El Paso and (ii) a Company-owned pipeline extending from Artesia to Orla, Texas, and from there west to El Paso. Products can be shipped by pipeline from El Paso to Albuquerque via a products pipeline system owned by Chevron Pipeline Company and to Tucson and Phoenix via a products pipeline system owned by Santa Fe Pacific Pipeline. The Company also owns a segment of a products pipeline running from Orla to Odessa, Texas, which is currently inactive. The Company believes that the proximity of the Navajo Refinery to its principal markets and the refinery's products distribution network provide a transportation cost advantage over Gulf Coast and West Coast refineries in supplying its markets. BUSINESS STRATEGY The Company's strategy has been, and continues to be, to optimize its refinery operations to increase the proportion of high value products it produces and to lower operating costs. As part of this strategy, the Company completed a $63 million expansion of the Navajo Refinery in December 1991, which, among other things, increased its refining capacity from 40,000 to 60,000 BPD. That expansion consisted principally of the addition of a new continuous catalytic regeneration unit, the modification of the FCC unit, the expansion of the naphtha desulfurizer and the installation of new sulphur and alkylation units. The installation of new equipment and the modification and upgrading of existing equipment as part of that expansion program increased the proportion of sour crude oils that the Navajo Refinery can process and increased the proportion of its throughput that can be converted into higher value products. The Company continues to evaluate improvements to its operating cost structure, refineries and crude oil gathering and product distribution systems. Management believes that certain enhancements and additions to the Navajo Refinery should better position the Company to respond to competitive pressures and to meet possible increases in demand for refined products. As part of its strategy, management intends to spend approximately $15 million over an 18-month period on identified capital enhancement projects at the Navajo Refinery. Those projects involve upgrades to the FCC and alkylation units, the construction of an isomerization unit and the installation of a new SHP unit. Management expects these projects to increase the Navajo Refinery's total gasoline production and to improve its ability to produce a greater proportion of "premium" (high octane) gasoline. In addition, these enhancements and plant additions are expected to improve management's flexibility to operate using different types of crude oils and other raw materials and to provide a platform for further refinery expansion, if appropriate, in the future. In addition, the Company is evaluating a number of other possible capital improvement projects, including (i) the redistribution of process activities between the Lovington and Artesia facilities in order to realize potential operating and transportation cost savings, (ii) other upgrades to improve the efficiency of the Navajo Refinery, (iii) modifications to increase 23 24 product pipeline distribution capacity and (iv) product pipeline reconditioning and construction to facilitate entry into new markets. See "Capital Improvement Projects -- Other Projects Under Consideration." NAVAJO REFINING COMPANY Facilities With the completion of a major expansion in December 1991, Navajo's refining capacity increased from 40,000 to 60,000 BPD. The Navajo Refinery has the ability to process a variety of sour crude oils and, as a result of the expansion, has increased the proportion of throughput that can be converted into high value light products (such as gasoline, diesel fuel and jet fuel). The expansion has also increased internal high octane capabilities and has augmented overall operating flexibility. The following table sets forth certain information concerning the operations of Navajo during the last five fiscal years and during the nine-month periods ending April 30, 1994 and 1995:
NINE MONTHS ENDED APRIL 30, YEARS ENDED JULY 31, ----------------- -------------------------------------------------- 1995 1994 1994 1993 1992 1991 1990 ------ ------ ------ ------ ------ ------ ------ Refinery production (BPD)(1)................ 62,200 56,400(2) 57,400(2) 58,600 48,900 38,800(2) 40,000 Crude charge (BPD)(3)..... 59,527 52,531(2) 54,089(2) 55,488 45,363 37,663(2) 39,524 Refinery utilization(BPD)(4)..... 99.2% 87.6%(2) 90.1%(2) 92.5% 87.8% 94.2%(2) 98.8% Average per barrel: Net sales............... $23.74 $22.39 $22.63 $25.39 $24.69 $29.89 $25.59 Raw materials costs(5)............. 19.10 16.35 17.20 20.26 20.53 24.67 19.83 ------ ------ ------ ------ ------ ------ ------ Gross margin............ $ 4.64 $ 6.04 $ 5.43 $ 5.13 $ 4.16 $ 5.22 $ 5.76 ====== ====== ====== ====== ====== ====== ======
- --------------- (1) Barrels per calendar day of refined products produced from crude oil and other raw materials. (2) Refinery production, crude charge and utilization rates were reduced as the result of a scheduled four-week turnaround for major maintenance. (3) Barrels per day of crude oil processed. (4) Crude charge divided by crude capacity. (5) Includes cost of refined products purchased for resale. Navajo's Artesia facility has fully integrated crude, FCC, vacuum distillation, alkylation, hydrodesulfurization and reforming units, and approximately 1.5 million barrels of feedstock and product tank storage, as well as other supporting units and office buildings at the site. The Artesia facilities are operated in conjunction with integrated refining facilities located in Lovington, New Mexico, approximately 65 miles east of Artesia. The principal equipment at Lovington consists of a crude unit and an associated vacuum unit. The Lovington facility processes crude oil into intermediate products, which are transported to Artesia through a Company-owned eight-inch pipeline or by tanker truck. 24 25 The following table shows the major units of the Navajo Refinery and their respective dates of construction or last major modification or upgrade:
YEAR OF COMPLETION OR UNITS MOST RECENT MAJOR MODIFICATION ----------------------------------------------------------- ------------------------------ Artesia Crude Distillation Unit............................ 1981 Artesia Vacuum Distillation Unit........................... 1981 Lovington Crude Distillation Unit.......................... 1991 Lovington Vacuum Distillation Unit......................... 1991 Diesel Hydrodesulfurization Unit........................... 1993 Naptha/Kerosene Hydrodesulfurization Unit.................. 1991 Fluid Catalytic Cracking Unit*............................. 1991 Alkylation Unit*........................................... 1991 Catalytic Reformer Unit.................................... 1991
- --------------- * To be upgraded as part of the capital improvements projects described under "Capital Improvement Projects -- Identified Refinery Enhancement Projects." The Company's 500 miles of crude gathering pipelines lead to the Artesia and Lovington facilities from various points in southeastern New Mexico. The Company distributes refined products from the Navajo Refinery to its principal markets primarily through (i) a Company-owned pipeline which extends from Artesia to El Paso and (ii) a Company owned pipeline extending from Artesia to Orla, Texas and from there west to El Paso. The Company has product storage at terminals in Tucson, Albuquerque, Artesia and El Paso in which the Company has 50% or greater interests. The Company also owns a segment of products pipeline running from Orla to Odessa, Texas, which is currently inactive. The Odessa pipeline segment could be utilized following certain capital expenditures for reconditioning. Markets and Competition The Navajo Refinery primarily serves the growing southwestern United States market, including El Paso, Albuquerque, Phoenix and Tucson, and the northern Mexico market. The Company's products are shipped by pipeline from El Paso to Albuquerque via a products pipeline system owned by Chevron Pipeline Company and to Tucson and Phoenix via a products pipeline system owned by Santa Fe Pacific Pipeline. The map below illustrates the Company's distribution system to its major markets. Access to the Company's markets by Gulf Coast refiners is limited primarily by the lack of available products pipelines. [MAP] 25 26 Growth in the Company's principal markets can be illustrated by the increasing gasoline consumption in the southwestern United States during the five years ended December 31, 1993, as shown in the following table: GASOLINE CONSUMPTION IN SOUTHWESTERN STATES
1993 1992 1991 1990 1989 --------- --------- --------- --------- --------- Barrels per Day: Arizona..................... 119,925 116,840 113,433 110,524 113,800 New Mexico.................. 56,866 54,688 53,518 52,387 52,898 Texas*...................... 578,414 564,309 554,748 576,802 569,204 Total U.S........... 7,606,918 7,471,633 7,322,877 7,453,498 7,480,858
COMPOUND ANNUAL GROWTH 1992-93 1991-92 1990-91 1989-90 RATE ------- ------- ------- ------- -------- Percentage Annual Change: Arizona............................... 2.6% 3.0% 2.6% (2.9)% 1.3% New Mexico............................ 4.0 2.2 2.2 (1.0) 1.8 Texas*................................ 2.5 1.7 (3.8) 1.3 0.4 Total U.S..................... 1.8 2.0 (1.8) (0.4) 0.4
- --------------- * Principal market served is El Paso. Source: U.S. Department of Transportation. The petroleum refining business is highly competitive. Among the Company's competitors are some of the world's largest integrated petroleum companies, which have their own crude oil supplies, distribution and marketing systems. The Company competes with independent refiners as well. Competition in particular geographic markets is affected primarily by the amounts of refined products produced by refineries located in such markets and by the availability of refined products and the cost of transportation to such markets from refineries located outside those markets. Diamond Shamrock, Inc., an independent refiner and marketer, is building a 420-mile, ten-inch refined products pipeline from its McKee refinery near Dumas, Texas to El Paso, the Company's largest market. Diamond Shamrock has announced that it expects to complete that pipeline, which will have an initial capacity of 25,000 BPD, in October 1995, and that it intends to use its pipeline to supply fuel to the El Paso, Arizona and northern Mexico markets. The Diamond Shamrock pipeline could substantially increase the supply of refined products in the Company's principal markets. In addition, there is excess pipeline capacity from the West Coast into the Company's Arizona markets. There can be no assurance that West Coast refiners will not seek to increase shipments of refined products into the Company's markets or that other industry participants will not seek to deliver their products to the Company's markets through existing pipelines, new pipelines or otherwise. In addition, in June 1995, an investor group announced that it is negotiating to purchase an existing crude oil pipeline running from West Texas to a refinery near Houston as part of the investor group's plan to reverse the line and extend it for use in transporting refined products from the Gulf Coast to El Paso. An increased supply of products in the Company's markets could adversely affect its sales volume and the prices it can obtain for its products. At times in the past, the common carrier pipelines used by the Company to serve the Arizona markets have been operated at or near their capacity and have been subject to periods of proration. In July 1993, the Company entered into a settlement agreement regarding that pipeline system. Under the agreement, the occurrence of certain defined events will require increases in the capacity of the pipeline. It is anticipated that this settlement lessens, at least in the foreseeable future, the likelihood of prolonged future constraints on the movement of the Company's products into Arizona. In addition, the common carrier pipeline used by the Company to serve the Albuquerque market currently is operating at or near capacity. As a result, the volume of refined products that the Company and other shippers have been able to deliver to this market at times has been limited. In general, no assurances can be given that the Company will not experience future constraints on its ability to deliver its products through common carrier pipelines or that any existing constraints will not 26 27 worsen. In particular, the flow of additional product into El Paso for shipment to Arizona, either as a result of the new Diamond Shamrock pipeline or otherwise, could result in the reoccurrence of such constraints. Crude Oil and Feedstock Supplies The Navajo Refinery is situated near the Permian Basin in an area with historically abundant crude supplies. The Company purchases crude oil from producers in nearby southeastern New Mexico and west Texas, from major oil companies and on the spot market. Crude oil is gathered through the Company's pipelines and tank trucks and through third party crude oil pipeline systems. Crude oil acquired in locations distant from the refinery is exchanged for crude oil that is transportable to the refinery. In 1993, the Company reactivated a subsidiary, Navajo Crude Oil Marketing Company, to facilitate the purchase of crude oil from leases in west Texas and New Mexico. Principal Products and Customers The Navajo Refinery converts approximately 86% of its raw materials throughput into high value light products. Set forth below is certain information regarding the principal products of Navajo during the last five fiscal years and during the nine-month periods ending April 30, 1994 and 1995:
NINE MONTHS ENDED APRIL 30, YEARS ENDED JULY 31, ---------------------------- ---------------------------------------------------------------------------- 1995 1994 1994 1993 1992 1991 1990 ------------ ------------ ------------ ------------ ------------ ------------ ------------ BPD % BPD % BPD % BPD % BPD % BPD % BPD % ------ ----- ------ ----- ------ ----- ------ ----- ------ ----- ------ ----- ------ ----- Product sales (percent of total sales volumes)(1): Gasolines....... 37,600 59.5% 32,700 56.6% 33,200 56.5% 32,600 53.4% 24,800 50.3% 18,500 47.7% 19,700 48.5% Diesel fuels.... 11,800 18.7 11,700 20.2 11,600 19.7 14,500 23.7 10,300 20.9 7,600 19.6 7,400 18.2 Jet fuels....... 6,900 10.9 6,100 10.6 6,500 11.1 5,900 9.7 6,200 12.6 7,200 18.5 8,400 20.7 Asphalt......... 4,000 6.3 4,700 8.1 4,900 8.3 5,500 9.0 5,000 10.1 2,900 7.5 2,500 6.2 LPG and other... 2,900 4.6 2,600 4.5 2,600 4.4 2,600 4.2 3,000 6.1 2,600 6.7 2,600 6.4 ------ ----- ------ ----- ------ ----- ------ ----- ------ ----- ------ ----- ------ ----- 63,200 100.0% 57,800 100.0% 58,800 100.0% 61,100 100.0% 49,300 100.0% 38,800 100.0% 40,600 100.0% ====== ===== ====== ===== ====== ===== ====== ===== ====== ===== ====== ===== ====== =====
- --------------- (1) Includes refined products purchased for resale representing 1.9%, 3.8%, 4.0%, 3.2%, 0.4%, 0.5% and 0.2%, respectively, of total sales volume for the periods shown in the table above. Light products are shipped by product pipelines or are made available at distant points by exchanges with others. Light products are also available to customers through truck loading facilities at the refineries and at terminals. The demand for the Company's gasoline and asphalt products has historically been stronger from March through October, which are the peak "driving" and road construction months, than during the rest of the year. The Company's principal customers for gasoline include other refiners, convenience store chains, independent marketers, an affiliate of PEMEX (the government-owned energy company of Mexico) and retailers. Navajo's gasoline is marketed in the southwestern United States, including the metropolitan areas of El Paso, Phoenix, Albuquerque, and Tucson, and in portions of northern Mexico. Diesel fuel is sold to other refiners, wholesalers, independent dealers and railroads. Jet fuel is sold primarily for military use. Military jet fuel is sold to the Defense Fuel Supply Center (the "DFSC") of the Defense Logistics Agency under a series of one-year contracts that can vary significantly from year to year. Navajo sold approximately 7,000 BPD of jet fuel to the DFSC in its 1994 fiscal year and has a contract to supply 8,100 BPD to the DFSC for the year ending September 30, 1995. Asphalt is sold to contractors and government authorities for highway construction and maintenance. Carbon black oil is sold for further processing, and LPGs are sold to petrochemical plants and are used as fuel in refinery operations. Approximately 12% of the Company's revenues for the first nine months of fiscal 1995 and 12% of revenues for fiscal 1994 resulted from the sale of military jet fuel to the United States government. Although there can be no assurance that the Company will be awarded such contracts in the future, the Company has had a supply contract with the United States government for each of the last 26 years. Approximately 7% of the Company's revenues for the first nine months of fiscal 1995 and 11% of revenues for fiscal 1994 resulted 27 28 from the sale of gasoline to an affiliate of PEMEX. Those sales were made under a contract that expires in mid-1997. The loss of the Company's supply contract with the United States government or with PEMEX could have a material adverse effect on the Company's results of operations. CAPITAL IMPROVEMENT PROJECTS Identified Refinery Enhancement Projects As part of its efforts to improve operating efficiencies, management currently intends to enhance the Navajo Refinery by upgrading the alkylation and FCC units, constructing an isomerization unit and installing a new SHP unit. These projects are intended to improve the Navajo Refinery's ability to produce a greater proportion of higher yielding products, principally "premium" (high octane) gasolines, and to enhance management's flexibility to choose among different types of crude oils and other raw materials in response to changing prices of supplies. The Company currently estimates that the cost of these projects will be approximately $15 million and expects to implement them over an 18-month period utilizing cash flows from operating activities. The Company's results of operations will be affected by future operating margins and other factors, some of which will be beyond its control. The modified FCC unit is expected to permit the refining of heavier feedstocks than are currently processed, which would enhance the Company's ability to take advantage of price differentials between sweet and sour crude oils. Similarly, the isomerization unit is expected to provide the Company with the ability to upgrade additional quantities of lower priced natural gasoline into finished gasoline. It is anticipated that the SHP unit and the upgraded alkylation unit will increase the refinery's production capacity for alkylate, a high octane gasoline blendstock, which also would contribute to the refinery's improved ability to produce premium unleaded gasolines and to upgrade natural gasoline into a refined product. Consequently, the Company expects that the enhancements to the Navajo Refinery will provide management with additional flexibility in managing the refinery's crude oil and other raw materials supplies. Further, based on industry studies concerning new environmental regulations promulgated by the California Air Resources Board and scheduled to go into effect in California in 1996, it appears that California refiners may require increased supplies of alkylates to produce the cleaner burning gasolines called for by the new regulations. In that event, the Navajo Refinery's increased production of alkylate could be made available for sale to California refineries. The Company expects to commence its identified refinery enhancement projects promptly. However, management intends to bring the new and upgraded equipment on-line in a manner that will minimize disruption to the Navajo Refinery's operations. Consequently, management does not expect to make the FCC modifications until the scheduled fall 1996 maintenance turnaround of the refinery. Other Capital Projects The Company is currently evaluating certain other enhancements and additions to the Navajo Refinery and the related supply and distribution systems to better position it to respond to competitive pressures and to meet possible increases in demand for refined products. Future capital projects that are being considered include (i) the redistribution of process activities between the Lovington and Artesia facilities in order to realize potential operating and transportation cost savings, (ii) other upgrades to improve the efficiency of the Navajo Refinery, (iii) modifications to increase product pipeline distribution capacity and (iv) product pipeline reconditioning and construction to facilitate entry into new markets. To the extent available, cash flows from operating activities could be used to finance the cost of these projects, although the Company may require additional funds if a decision were made to implement some or all of these projects. There can be no assurance that the Company will have sufficient sources of funds to implement any or all of these other capital projects. MONTANA REFINING COMPANY MRC owns a 7,000 BPD petroleum refinery near Great Falls, Montana, which can process a range of crude oils and which serves primarily the State of Montana. For the last three fiscal years, excluding downtime 28 29 for scheduled maintenance and turnarounds, the Montana Refinery has operated at an average annual crude capacity utilization rate of approximately 94%. The following table sets forth certain information regarding the principal products of MRC during the last five years and during the nine-month periods ending April 30, 1994 and 1995:
NINE MONTHS ENDED APRIL 30, YEARS ENDED JULY 31, ------------------------------ --------------------------------------------------------------------------------- 1995 1994 1994 1993 1992 1991 1990 ------------- ------------- ------------- ------------- ------------- ------------- ------------- BPD % BPD % BPD % BPD % BPD % BPD % BPD % ----- ----- ----- ----- ----- ----- ----- ----- ----- ----- ----- ----- ----- ----- Product sales (percent of total sales volumes)(1): Gasolines... 2,300 36.5% 2,700 40.3% 2,700 38.6% 2,700 39.1% 2,800 42.4% 2,400 40.0% 2,400 36.4% Diesel fuels... 1,700 27.0 1,700 25.4 1,700 24.3 1,600 23.2 1,500 22.7 1,400 23.4 1,400 21.2 Jet fuels.. 900 14.3 1,200 17.9 1,100 15.7 1,200 17.4 1,100 16.7 900 15.0 1,200 18.2 Asphalt.... 1,100 17.4 900 13.4 1,300 18.6 1,200 17.4 1,100 16.7 1,100 18.3 1,300 19.7 LPG and other.... 300 4.8 200 3.0 200 2.8 200 2.9 100 1.5 200 3.3 300 4.5 ----- ----- ----- ----- ----- ----- ----- ----- ----- ----- ----- ----- ----- ----- Total 6,300 100.0% 6,700 100.0% 7,000 100.0% 6,900 100.0% 6,600 100.0% 6,000 100.0% 6,600 100.0% ===== ===== ===== ===== ===== ===== ===== ===== ===== ===== ===== ===== ===== =====
- --------------- (1) Includes refined products purchased for resale representing 9.0%, 3.1%, 3.4%, 3.2%, 2.6%, 2.1% and 1.1%, respectively, of total sales volume for the periods shown in the table above. The Montana Refinery obtains its supply of crude oils primarily from suppliers in Canada via a 93-mile, Company-owned pipeline, which runs from near the Canadian border. The Montana Refinery's principal markets include Great Falls, Helena, Bozeman and Billings, Montana. MRC competes principally with three other Montana refineries. JET FUEL TERMINAL The Company owns and operates a 120,000 barrel capacity jet fuel terminal near Mountain Home, Idaho, which serves as a terminalling facility for jet fuel sold by unaffiliated producers to the Mountain Home United States Air Force Base. NAVAJO WESTERN ASPHALT COMPANY Navajo Western Asphalt Company, a wholly-owned subsidiary of the Company, operates an asphalt marketing facility near Phoenix. The Company has recently completed construction of asphalt processing and storage facilities that should allow it to expand this operation. In addition to serving as a marketing outlet for asphalt produced by Navajo at the Lovington facility, Navajo Western markets asphalt for third parties. EXPLORATION AND PRODUCTION The Company contracts with two independent oil and gas consulting groups that identify oil and gas exploration and production projects for the Company. The scope of this activity is presently modest relative to the Company's refining operations. For fiscal 1995, the Company has budgeted approximately $4 million for capital expenditures related to oil and gas exploration activities. The majority of that budget will be used to fund the anticipated costs to complete production facilities at two offshore properties in which the Company has an interest. EMPLOYEES AND LABOR RELATIONS As of April 30, 1995, the Company had approximately 540 employees, of whom 451 were employed by the Navajo Refinery and 73 were employed at the Montana Refinery. Of its employees, 216 are covered by collective bargaining agreements ("covered employees"). Contracts relating to the covered employees at all facilities were negotiated during 1993 and will expire in 1996. The Company considers its employee relations to be good. 29 30 REGULATION Refinery operations are subject to federal, state and local laws regulating the discharge of matter into the environment or otherwise relating to the protection of the environment. Over the years, there have been and continue to be ongoing communications, including notices of violations, and discussions about environmental matters, between the Company and federal and state authorities, some of which have resulted in changes in operating procedures and certain capital expenditures by the Company. Compliance with applicable environmental laws and regulations will continue to have an impact on the Company's operations and capital requirements. For example, the final form of the regulations implementing recent amendments to the Clean Air Act could have a substantial impact on the future capital spending requirements of the Company and the refining industry as a whole. The EPA has promulgated regulations which substantially reduced the allowable sulfur content of diesel fuel for sales starting in October 1993. In fiscal 1994, the Company completed projects which allow Navajo and MRC to meet this new standard. Effective January 1, 1995, certain cities in the country were required to use only reformulated gasoline ("RFG"), a cleaner burning fuel. While none of the Company's principal markets presently require RFG, this requirement could be implemented over time. Further, other requirements of the Clean Air Act could cause the Company to be required to expend substantial amounts for compliance at its refineries. Expenditures in connection with Clean Air Act at the Montana Refinery could be proportionally larger than similar expenditures anticipated for the Navajo Refinery. However, the specifics of these requirements and their attendant costs are not presently determinable. The Company is and has been the subject of various state, federal and private proceedings relating to environmental regulations, conditions and inquiries. The most significant of these is the enforcement action which has been brought by the DOJ, on behalf of the EPA, and which is discussed in "Management's Discussion and Analysis of Results of Operations and Financial Condition -- Financial Condition" and in Note 12 to the Consolidated Financial Statements for the year ended July 31, 1994 included elsewhere herein. In addition to the expenditures that will likely be incurred in connection with a resolution of this matter, current or future environmental regulations likely will require additional remediation or other expenditures at the Navajo and Montana Refineries. The extent of any such expenditures cannot be presently determined. The Company's operations are also subject to various laws and regulations relating to occupational health and safety. The Company maintains safety, training and maintenance programs as part of its ongoing efforts to ensure compliance with applicable laws and regulations. Moreover, while recently enacted comprehensive health and safety legislation has required, and will continue to require, substantial expenditures and modifications of procedures, the Company believes it is taking the appropriate steps to ensure compliance. Notwithstanding the Company's efforts, following an eight-month series of inspections at MRC, the Occupational Safety and Health Administration recently issued numerous citations alleging a variety of matters of noncompliance. MRC has contested all citations and it cannot presently determine the extent of any fines and related costs for which it will ultimately be responsible. The parties have recently been engaged in substantive settlement discussions; however, no assurance can be given that a settlement will ultimately be reached. INSURANCE The Company's operations (including its limited exploration and production activities) are subject to normal business hazards, including fire, explosion and weather-related perils. The Company maintains various insurance coverages, including business interruption insurance, subject to certain deductibles. The Company is not fully insured against those risks that are not fully insurable or for which coverage is unavailable or premium costs are prohibitive. LEGAL PROCEEDINGS In July 1993, the DOJ, acting on behalf of the EPA, filed a complaint in the United States District Court for the District of New Mexico alleging that Navajo, beginning in September 1990 and continuing until the present, had violated and continues to violate RCRA and implementing regulations of the EPA by treating, 30 31 storing and disposing of certain hazardous wastes without necessary authorization and without compliance with regulatory requirements. The complaint seeks a court order directing Navajo to comply with these regulatory standards and civil penalties for the alleged non-compliance. The Company believes that the parties are in the final stages of negotiations that should resolve the litigation. Based on these negotiations, the Company would close the existing evaporation ponds of its wastewater management system and implement an alternative waste water treatment system. Any settlement with DOJ and EPA also is expected to involve payment of a civil penalty. See "Risk Factors -- Environmental Regulation," "Management's Discussion and Analysis of Results of Operations and Financial Condition" and the Notes to the Consolidated Financial Statements included elsewhere herein. The Company is a party to various other litigation and proceedings which it believes, based on advice of counsel, will not have a material adverse impact on its financial condition or results of operations. MANAGEMENT AND DIRECTORS EXECUTIVE OFFICERS The following table identifies the executive officers of the Company:
EXECUTIVE NAME AGE POSITION OFFICER SINCE ---------------------------- --- ---------------------------------------- ------------- Lamar Norsworthy............ 48 Chairman of the Board, President and 1971 Chief Executive Officer Jack P. Reid................ 58 Executive Vice President, Refining and 1976 Director William J. Gray............. 54 Senior Vice President, Marketing and 1976 Supply Matthew P. Clifton.......... 43 Senior Vice President 1988 David G. Blair.............. 37 Vice President, Marketing Asphalt and 1994 LPG Christopher L. Cella........ 38 Vice President, General Counsel and 1990 Secretary Karl N. Knapp............... 37 Vice President 1994 John A. Knorr............... 44 Vice President, Crude Oil Supply and 1988 Trading Virgil R. Langford.......... 50 Vice President, Refining 1989 Mike Mirbagheri............. 56 Vice President, International Crude Oil 1982 and Refined Products Henry A. Teichholz.......... 52 Vice President, Treasurer and Controller 1984 Gregory A. White............ 37 Vice President, Marketing Light Oils 1994
In addition to the persons listed above, Kathryn Walker, age 44, was appointed Controller of Navajo Refining Company in August 1993; prior thereto she served from November 1985 as Assistant Controller of Navajo. All officers of the Company are elected annually to serve until their successors have been elected. Mr. Cella joined the Company in 1990, having previously been associated with the law firm of Gibson, Dunn & Crutcher since 1982. Mr. Clifton previously served as Vice President, Economics, Engineering and Legal Affairs from 1988 to 1991. Mr. Knorr serves as the General Manager of MRC. Mr. Langford became Navajo's refinery manager in January 1989 and had held a similar position with MRC since 1985. Messrs. Blair, Knapp and White were elected to their respective positions in September 1994. Mr. Blair has served as Marketing Manager of Asphalt and LPG of Navajo since 1989 and previously held various 31 32 marketing and supply positions. Mr. Knapp joined the Company in 1992 and served as Director of Corporate Development from 1992 to 1994. Mr. Knapp was Director of Corporate Planning for Northwest Airlines from 1991 to 1992, and prior to that was associated with the management consulting firm of Monitor Company from 1987 to 1991. Mr. White has served as Marketing Manager of Light Oils of Navajo since 1989 and previously held various marketing and supply positions. DIRECTORS The following table identifies the directors of the Company:
NAME AGE DIRECTOR SINCE -------------------------------------------------------- --- -------------- W. John Glancy.......................................... 53 1975 Marcus R. Hickerson..................................... 68 1960 A.J. Losee.............................................. 70 1978 Thomas K. Matthews, II.................................. 69 1978 Robert G. McKenzie...................................... 56 1992 Lamar Norsworthy........................................ 48 1967 E.I. Parsons............................................ 66 1976 Jack P. Reid............................................ 58 1977
W. John Glancy has been a partner in Weil, Gotshal & Manges since April 1995 and previously practiced in the Law Offices of W. John Glancy from January 1991. From 1988 to 1990, Mr. Glancy was a partner in the law firm of Hughes & Luce. Marcus R. Hickerson has been a consultant to Centex Development Company since 1987. A. J. Losee is a shareholder in the Artesia, New Mexico law firm of Losee, Carson, Haas & Carroll, P.A., and has practiced law for more than 40 years. Thomas K. Matthews, II, is a financial consultant. Robert G. McKenzie has been Executive Vice President and Chief Operating Officer of Brown Brothers Harriman Trust Company of Texas since January 1990. Previously, he was Executive Vice President of NCNB Texas National Bank and of First Republic Bank Dallas N.A. and Senior Vice President of RepublicBank Dallas, N.A. Lamar Norsworthy is Chairman of the Board, Chief Executive Officer and President of the Company. E. I. Parsons until his retirement in January 1992 was Vice Chairman of the Board of the Company. Jack P. Reid is Executive Vice President, Refining, of the Company. 32 33 SELLING STOCKHOLDERS The following table sets forth the names of the Selling Stockholders, the aggregate number of shares of Common Stock identified by the Selling Stockholders as being beneficially owned by them as of May 15, 1995, and the aggregate number of shares of Common Stock being sold by each of them in the Offering.
NUMBER OF NUMBER OF NUMBER OF SHARES OF PERCENT OF COMMON SHARES OF SHARES OF COMMON STOCK STOCK OUTSTANDING COMMON STOCK COMMON STOCK TO BE OWNED --------------------- NAME AND ADDRESS OF OWNED BEFORE TO BE SOLD AFTER BEFORE AFTER BENEFICIAL OWNER OFFERING IN OFFERING OFFERING OFFERING OFFERING - ---------------------------------------------- ------------ ------------ ------------ -------- -------- Brown Brothers Harriman Trust Company of Texas, as trustee of trusts in the names of Betty Regard, Margaret Simmons, Suzanne Bartolucci, Lamar Norsworthy and Nona Barrett..................................... 2,208,844 697,708 1,511,136 26.8% 18.3% David Norsworthy(1)........................... 250,752 98,000 152,752 3.0 1.9 Lamar Norsworthy(2)(3)........................ 428,581 102,146 326,435 5.2 4.0 Nona Barrett(4)............................... 430,278 102,146 328,132 5.2 4.0
- --------------- (1) Does not include 93,854 shares held by a trust of which this Selling Shareholder is a beneficiary. In addition, does not include 285,858 shares beneficially owned by three trusts of which the Selling Shareholder is a co-trustee; the Selling Shareholder disclaims that he is a beneficial owner except as to 1,430 of these shares. (2) Does not include 93,854 shares held by a trust of which this Selling Shareholder is a beneficiary, which shares are being sold in the Offering by Brown Brothers Harriman Trust Company of Texas as trustee of such trust. In addition, does not include 285,858 shares beneficially owned by three trusts of which the Selling Shareholder is a co-trustee; the Selling Shareholder disclaims that he is a beneficial owner except as to 1,430 of these shares. (3) Lamar Norsworthy is Chairman of the Board, President, Chief Executive Officer and a director of the Company. (4) Does not include 93,854 shares held by a trust of which this Selling Shareholder is a beneficiary, which shares are being sold in the Offering by Brown Brothers Harriman Trust Company of Texas as trustee of such trust. In addition, does not include 285,858 shares beneficially owned by David Norsworthy, Lamar Norsworthy, and Brown Brothers Harriman Trust Company of Texas, as co-trustees of trusts for the benefit of the Selling Shareholder, David Norsworthy and Lamar Norsworthy. 33 34 DESCRIPTION OF COMMON STOCK The following description of the Common Stock is qualified in its entirety by reference to the portions of the Company's Restated Certificate of Incorporation and Revised By-laws, which have been filed as exhibits to the Registration Statement of which this Prospectus is a part. The Company is authorized to issue 20,000,000 shares of Common Stock, par value of $0.01 per share. Except as expressly required by law or provided in the Restated Certificate of Incorporation of the Company or the Revised By-laws of the Company, each holder of Common Stock shall be entitled to one vote, in person or by proxy, for each share of Common Stock recorded in the stock records of the Company in such stockholder's name. No holder of the Common Stock shall be entitled as of right to subscribe for, purchase or receive any part of any new or additional shares of stock of any class, whether now or hereafter authorized, or of bonds, debentures or other evidences of indebtedness convertible into or exchangeable for stock, but all such new or additional shares of stock of any class, or bonds, debentures or other evidences of indebtedness convertible into or exchangeable for stock, may be issued and disposed of by the Board of Directors on such terms and for such consideration, so far as may be permitted by law, and to such person or persons as the Board of Directors in its absolute discretion may deem advisable. The holders of the Common Stock have such rights to receive dividends and to receive distributions upon a dissolution or liquidation of the Company as are provided for under the General Corporation Law of Delaware. In addition to the Common Stock, the Company is authorized to issue up to 1,000,000 shares of preferred stock, par value $1.00 per share (the "Preferred Stock"), having such designations as may be fixed by the Board of Directors of the Company. The rights of the holders of the Common Stock are subject to the terms of any Preferred Stock issued, and in the event of a liquidation or dissolution of the Company, would be subordinate to distributions made with respect to the liquidation preferences of holders of Preferred Stock, if any shares of Preferred Stock were then outstanding. UNDERWRITING Subject to the terms and conditions set forth in the Purchase Agreement (the "Purchase Agreement") among the Company, the Selling Stockholders and each of the underwriters named below (the "Underwriters"), the Selling Stockholders have agreed to sell to each of the Underwriters, and each of the Underwriters has severally agreed to purchase from the Selling Stockholders the number of shares of Common Stock set forth below opposite their respective names. The Underwriters are committed to purchase all of such shares if any are purchased. Under certain circumstances, the commitments of nondefaulting Underwriters may be increased as set forth in the Purchase Agreement.
NUMBER OF UNDERWRITERS SHARES --------------------------------------------------------------------------- --------- Merrill Lynch, Pierce, Fenner & Smith Incorporated.................................................. 500,000 CS First Boston Corporation................................................ 500,000 --------- Total......................................................... 1,000,000 =========
The Underwriters have advised the Company and the Selling Stockholders that the Underwriters propose to offer the shares of Common Stock to the public initially at the public offering price set forth on the cover page of this Prospectus, and to certain dealers at such price less a concession not in excess of $.60 per share. The Underwriters may allow, and such dealers may re-allow, a discount not in excess of $.10 per share on sales to certain other dealers. After the public offering, the public offering price, concession and discount may be changed. The Selling Stockholders have granted the Underwriters an option to purchase up to 150,000 additional shares of Common Stock at the initial public offering price, less the underwriting discount. Such option, which expires 30 days after the date of this Prospectus, may be exercised solely to cover over-allotments. To the extent that the Underwriters exercise such options, each of the Underwriters will be obligated, subject to certain conditions, to purchase approximately the same percentage of the option shares that the number of 34 35 shares of Common Stock to be purchased initially by that Underwriter bears to the total number of shares to be purchased initially by the Underwriters. The Company and the Selling Stockholders have agreed to indemnify the Underwriters against certain liabilities, including liabilities under the Securities Act, or to contribute to payments the Underwriters may be required to make in respect thereof. Each of the Company, the Selling Stockholders and certain trusts for the benefit of the Selling Stockholders has agreed that it will not, without the prior written consent of the Underwriters, directly or indirectly, sell, offer to sell, grant any option for the sale of or otherwise dispose of, any shares of Common Stock or any security convertible into or exchangeable or exercisable for any such shares of Common Stock for a period of 180 days from the date of this Prospectus. LEGAL MATTERS Certain legal matters with respect to the Common Stock offered hereby will be passed upon for the Selling Stockholders by Weil, Gotshal & Manges (a partnership including professional corporations), Dallas, Texas. Certain legal matters in connection with the sale of the Common Stock offered hereby will be passed upon for the Underwriters by Baker & Botts L.L.P., Dallas, Texas. W. John Glancy, a director of the Company, is a partner in Weil, Gotshal & Manges and beneficially owns 200 shares of Common Stock. Baker & Botts, L.L.P. from time to time provides legal services to the Company. EXPERTS The consolidated financial statements of Holly Corporation at July 31, 1994 and 1993, and for each of the three years in the period ended July 31, 1994, appearing in this Prospectus and Registration Statement have been audited by Ernst & Young LLP, independent auditors, as set forth in their report thereon appearing elsewhere herein and in the Registration Statement, and are included herein in reliance upon such report given upon the authority of such firm as experts in accounting and auditing. 35 36 INDEX TO CONSOLIDATED FINANCIAL STATEMENTS
PAGE ----- Annual Financial Statements Report of Independent Auditors...................................................... F-2 Consolidated Balance Sheet at July 31, 1994 and 1993................................ F-3 Consolidated Statement of Income for the years ended July 31, 1994, 1993 and 1992... F-4 Consolidated Statement of Cash Flows for the years ended July 31, 1994, 1993 and 1992............................................................................. F-5 Consolidated Statement of Stockholders' Equity for the years ended July 31, 1994, 1993 and 1992..................................................... F-6 Notes to Consolidated Financial Statements.......................................... F-7 Interim Financial Statements Condensed Consolidated Balance Sheet -- April 30, 1995 (Unaudited).................. F-17 Condensed Consolidated Statement of Income (Unaudited) for the nine months ended April 30, 1995 and 1994.......................................................... F-18 Condensed Consolidated Statement of Cash Flows (Unaudited) for the nine months ended April 30, 1995 and 1994.......................................................... F-19 Notes to Condensed Consolidated Financial Statements................................ F-20
F-1 37 REPORT OF ERNST & YOUNG LLP INDEPENDENT AUDITORS The Board of Directors and Stockholders of Holly Corporation We have audited the accompanying consolidated balance sheet of Holly Corporation (the "Company") at July 31, 1994 and 1993, and the related consolidated statements of income, cash flows and stockholders' equity for each of the three years in the period ended July 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 consolidated financial statements referred to above present fairly, in all material respects, the consolidated financial position of Holly Corporation at July 31, 1994 and 1993, and the consolidated results of its operations and its cash flows for each of the three years in the period ended July 31, 1994, in conformity with generally accepted accounting principles. ERNST & YOUNG LLP Dallas, Texas September 20, 1994 F-2 38 HOLLY CORPORATION CONSOLIDATED BALANCE SHEET
JULY 31, --------------------- 1994 1993 -------- -------- ($ IN THOUSANDS, EXCEPT PER SHARE AMOUNTS) ASSETS Current assets Cash and cash equivalents (Note 6)................................... $ 3,297 $ 6,631 Accounts receivable (Notes 3 and 6).................................. 94,280 76,867 Inventories (Notes 4 and 6).......................................... 43,995 37,972 Income taxes receivable.............................................. 697 -- Prepayments and other................................................ 9,340 7,082 -------- -------- Total current assets.............................................. 151,609 128,552 Properties, plants and equipment, net (Note 5)......................... 128,962 118,821 Other assets........................................................... 1,243 2,434 -------- -------- $281,814 $249,807 ======== ======== LIABILITIES AND STOCKHOLDERS' EQUITY Current liabilities Accounts payable..................................................... $112,084 $ 86,787 Accrued liabilities.................................................. 14,945 16,648 Income taxes payable................................................. 736 7,364 Current maturities of long-term debt (Note 6)........................ 5,608 5,608 -------- -------- Total current liabilities......................................... 133,373 116,407 Deferred income taxes (Note 7)......................................... 14,829 12,474 Long-term debt, less current maturities (Note 6)....................... 68,840 74,448 Contingencies (Notes 10 and 12) Stockholders' equity (Notes 6, 8 and 9) Preferred stock, $1.00 par value -- 1,000,000 shares authorized; none issued............................................................ -- -- Common stock, $.01 par value -- 20,000,000 shares authorized; 8,650,282 shares issued........................................... 87 87 Additional capital................................................... 6,132 6,132 Retained earnings.................................................... 59,942 42,058 -------- -------- 66,161 48,277 Common stock held in treasury, at cost -- 396,768 shares............. (569) (569) Deferred charge -- amount due from ESOP.............................. (820) (1,230) -------- -------- Total stockholders' equity................................... 64,772 46,478 -------- -------- $281,814 $249,807 ======== ========
See accompanying notes. F-3 39 HOLLY CORPORATION CONSOLIDATED STATEMENT OF INCOME
YEARS ENDED JULY 31, ---------------------------------- 1994 1993 1992 -------- -------- -------- ($ IN THOUSANDS, EXCEPT PER SHARE AMOUNTS) REVENUES Net sales................................................ $550,903 $629,884 $506,185 Miscellaneous............................................ 1,417 737 483 -------- -------- -------- 552,320 630,621 506,668 COSTS AND EXPENSES Cost of sales............................................ 480,916 565,638 474,151 General and administrative............................... 12,369 11,951 9,263 Depreciation, depletion and amortization................. 10,871 11,344 10,085 Exploration expenses, including dry holes................ 4,441 2,867 2,005 Miscellaneous............................................ 183 150 148 -------- -------- -------- 508,780 591,950 495,652 -------- -------- -------- Income from operations..................................... 43,540 38,671 11,016 OTHER INCOME (EXPENSE) Interest income.......................................... 447 169 432 Interest expense (Note 6)................................ (8,985) (9,523) (10,086) Other (Note 11).......................................... -- 4,000 (700) -------- -------- -------- (8,538) (5,354) (10,354) -------- -------- -------- Income before income taxes and cumulative effect of change in accounting for income taxes........................... 35,002 33,317 662 Income tax provision (benefit) (Notes 2, 7 and 10) Current.................................................. 11,785 12,647 (966) Deferred................................................. 2,500 737 (1,131) -------- -------- -------- 14,285 13,384 (2,097) -------- -------- -------- Income before cumulative effect of change in accounting principle..................................... 20,717 19,933 2,759 Cumulative effect to August 1, 1992 of change in accounting for income taxes (Note 2)..................... -- (958) -- -------- -------- -------- Net income................................................. $ 20,717 $ 18,975 $ 2,759 ======== ======== ======== Income per common share Income before cumulative effect of change in accounting principle.................................. $ 2.51 $ 2.42 $ .33 Cumulative effect to August 1, 1992 of change in accounting for income taxes........................... -- (.12) -- -------- -------- -------- Net income............................................... $ 2.51 $ 2.30 $ .33 ======== ======== ======== Cash dividends paid per share.............................. $ .35 $ .30 $ .45 ======== ======== ======== Average number of shares of common stock outstanding (in thousands)........................................... 8,254 8,254 8,254 ======== ======== ========
See accompanying notes. F-4 40 HOLLY CORPORATION CONSOLIDATED STATEMENT OF CASH FLOWS
YEARS ENDED JULY 31, ---------------------------------- 1994 1993 1992 -------- -------- -------- ($ IN THOUSANDS) CASH FLOWS FROM OPERATING ACTIVITIES Net income............................................... $ 20,717 $ 18,975 $ 2,759 Adjustments to reconcile net income to net cash provided by operating activities Depreciation, depletion and amortization.............. 10,871 11,344 10,085 Deferred income taxes................................. 2,500 737 (1,131) Dry hole costs and leasehold impairment............... 1,509 1,175 369 Cumulative effect to August 1, 1992 of change in accounting for income taxes......................... -- 958 -- Changes in operating assets and liabilities (Increase) decrease in accounts receivable.......... (17,413) 12,222 (27,388) Increase in inventories............................. (6,023) (2,365) (5,984) (Increase) decrease in income taxes receivable...... (697) 2,115 (1,876) Increase in prepayments and other................... (2,403) (197) (1,581) (Increase) decrease in accounts payable............. 25,297 (19,964) 26,005 (Increase) decrease in accrued liabilities.......... (1,703) 6,419 858 (Increase) decrease in income taxes payable......... (6,572) 7,427 (1,970) Other, net............................................ 1,601 (109) 815 -------- -------- -------- Net cash provided by operating activities........ 27,684 38,737 961 CASH FLOWS FROM FINANCING ACTIVITIES Increase (decrease) in notes payable.................. -- (10,500) 10,500 Reduction of long-term debt........................... (5,608) (108) (474) Issuance costs of debt................................ -- (291) -- Cash dividends........................................ (2,889) (2,476) (3,714) -------- -------- -------- Net cash provided by (used for) financing activities..................................... (8,497) (13,375) 6,312 CASH FLOWS FROM INVESTING ACTIVITIES Additions to properties, plants and equipment......... (22,521) (20,120) (22,317) Additional cost of partnership........................ -- -- (739) -------- -------- -------- Net cash used for investing activities........... (22,521) (20,120) (23,056) -------- -------- -------- CASH AND CASH EQUIVALENTS (Increase) decrease for the year...................... (3,334) 5,242 (15,783) Beginning of year..................................... 6,631 1,389 17,172 -------- -------- -------- End of year........................................... $ 3,297 $ 6,631 $ 1,389 ======== ======== ========
See accompanying notes. F-5 41 HOLLY CORPORATION CONSOLIDATED STATEMENT OF STOCKHOLDERS' EQUITY
AMOUNT DUE TOTAL COMMON ADDITIONAL RETAINED TREASURY FROM STOCKHOLDERS' STOCK CAPITAL EARNINGS STOCK ESOP EQUITY ------ ---------- -------- -------- --------- ------------ ($ IN THOUSANDS) BALANCE AT JULY 31, 1991.... $ 87 $6,132 $26,212 $ (569) $(2,051) $ 29,811 Net income.................. -- -- 2,759 -- -- 2,759 Dividends paid.............. -- -- (3,714) -- -- (3,714) Reduction in amount due from ESOP...................... -- -- -- -- 410 410 Tax benefit of dividends paid to ESOP.............. -- -- 239 -- -- 239 ----- -------- ------- ------- -------- ---------- BALANCE AT JULY 31, 1992.... 87 6,132 25,496 (569) (1,641) 29,505 Net income.................. -- -- 18,975 -- -- 18,975 Dividends paid.............. -- -- (2,476) -- -- (2,476) Reduction in amount due from ESOP...................... -- -- -- -- 411 411 Tax benefit of dividends paid to ESOP on unallocated shares........ -- -- 63 -- -- 63 ----- -------- ------- ------- -------- ---------- BALANCE AT JULY 31, 1993.... 87 6,132 42,058 (569) (1,230) 46,478 Net income.................. -- -- 20,717 -- -- 20,717 Dividends paid.............. -- -- (2,889) -- -- (2,889) Reduction in amount due from ESOP...................... -- -- -- -- 410 410 Tax benefit of dividends paid to ESOP on unallocated shares........ -- -- 56 -- -- 56 ----- -------- ------- ------- -------- ---------- BALANCE AT JULY 31, 1994.... $ 87 $6,132 $59,942 $ (569) $ (820) $ 64,772 ===== ======== ======= ======= ======== ==========
See accompanying notes. F-6 42 HOLLY CORPORATION NOTES TO CONSOLIDATED FINANCIAL STATEMENTS JULY 31, 1994, 1993 AND 1992 1. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES PRINCIPLES OF CONSOLIDATION The Company is principally engaged in the refining of petroleum products. Although the Company is also engaged in certain oil and gas exploration and production activities, such activities do not represent a significant segment of the Company's assets or operations. The consolidated financial statements include the accounts of the Company, its subsidiaries and Montana Refining Company, a Partnership (MRC). CASH EQUIVALENTS For purposes of the statement of cash flows, the Company considers all highly liquid investments with a maturity of three months or less at the time of purchase to be cash equivalents. INVENTORIES Inventories are stated at the lower of cost, using the last-in, first-out (LIFO) method for crude oil and refined products and the average cost method for materials and supplies, or market. REVENUE RECOGNITION Sales and related cost of sales are recognized when products are shipped to customers and title passes. Sales are reported exclusive of excise taxes. DEPRECIATION Depreciation is provided by the straight-line method over the estimated useful lives of the assets, primarily 10 to 30 years for refining and pipeline facilities and 3 to 10 years for corporate and other assets. OIL AND GAS EXPLORATION AND DEVELOPMENT The Company accounts for the acquisition, exploration, development and production costs of its oil and gas activities using the successful efforts method of accounting. Lease acquisition costs are capitalized; undeveloped leases are written down when determined to be impaired and written off upon expiration or surrender. Geological and geophysical costs and delay rentals are expensed as incurred. Exploratory well costs are initially capitalized, but if the effort is unsuccessful, the costs are charged against earnings. Development costs, whether or not successful, are capitalized. Productive properties are stated at the lower of amortized cost or estimated realizable value of underlying proved oil and gas reserves. Depreciation, depletion and amortization of such properties is computed by the unit-of-production method. EARNINGS PER SHARE Earnings per share amounts are based upon the weighted average number of common shares outstanding during each period. FUTURES CONTRACTS The Company enters into futures contracts to hedge a portion of the price risk associated with crude oil and refined products. Gains or losses on contracts are recognized when the related inventory is sold or the hedged transaction is consummated. F-7 43 HOLLY CORPORATION NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED) JULY 31, 1994, 1993 AND 1992 2. ACCOUNTING CHANGE Effective August 1, 1992, the Company adopted Statement of Financial Accounting Standards (SFAS) No. 109, "Accounting for Income Taxes", which amends the accounting for income taxes from the deferral method to the liability method. Under the liability method, deferred taxes are stated at the income tax rates currently in effect or scheduled to be implemented rather than at the tax rate in effect when the taxes were provided. The cumulative effect of this accounting change through the 1992 fiscal year was a $958,000 increase in the Company's deferred tax liability at August 1, 1992. This additional income tax expense was reflected as a reduction of $958,000 in net income in the first quarter of the 1993 fiscal year or $.12 per share. Excluding the provision for the cumulative effect upon adoption of the new standard, the effect of the change on net income was not material. 3. ACCOUNTS RECEIVABLE
1994 1993 ------- ------- ($ IN THOUSANDS) Product.......................................................... $45,259 $40,412 Crude oil resales................................................ 49,021 36,455 ------- ------- $94,280 $76,867 ======= =======
Crude oil resales accounts receivable principally represent the sell side of reciprocal crude oil buy/sell exchange arrangements involved in supplying crude oil to the refineries, with an approximate like amount reflected in accounts payable. The net differential of these crude oil buy/sell exchanges is reflected in cost of sales. The exchange differentials result principally from crude oil type and location differences. Credit losses are provided for in the financial statements and consistently have been minimal. 4. INVENTORIES
1994 1993 ------- ------- ($ IN THOUSANDS) Crude oil and refined products................................... $37,949 $32,625 Materials and supplies........................................... 6,046 5,347 ------- ------- $43,995 $37,972 ======= =======
The excess of current costs over the LIFO value of inventory was $12,228,000 and $5,990,000 at July 31, 1994 and 1993, respectively. 5. PROPERTIES, PLANTS AND EQUIPMENT
1994 1993 -------- -------- ($ IN THOUSANDS) Properties, plants and equipment, at cost Refining and pipeline facilities............................. $224,540 $207,935 Oil and gas exploration and development...................... 10,607 6,651 Corporate and other.......................................... 1,038 1,017 -------- -------- 236,185 215,603 Accumulated depreciation, depletion and amortization........... 107,223 96,782 -------- -------- $128,962 $118,821 ======== ========
F-8 44 HOLLY CORPORATION NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED) JULY 31, 1994, 1993 AND 1992 Refining and pipeline facilities at July 31, 1994 and 1993 include $4,452,000 and $12,002,000, respectively, of construction in progress which was not being depreciated at those dates, pending completion of the construction projects. 6. DEBT
1994 1993 ------- ------- ($ IN THOUSANDS) Senior Notes..................................................... $74,400 $80,000 Other............................................................ 48 56 ------- ------- 74,448 80,056 Less current maturities of long-term debt........................ 5,608 5,608 ------- ------- $68,840 $74,448 ======= =======
SENIOR NOTES In June 1991, the Company sold $80 million of Senior Notes to a group of insurance companies. The Senior Notes were issued in two Series and are unsecured. The Series A Notes are in the principal amount of $28 million, have a 7-year life, require equal annual principal payments of $5,600,000 beginning June 15, 1994 and bear interest at 9.72%. The Series B Notes are in the principal amount of $52 million, have a 10-year life, require equal annual principal payments of $8,667,000 beginning June 15, 1996 and bear interest at 10.16%. The note agreement imposes certain restrictive covenants, including limitations on liens, additional indebtedness, sale of assets, investments, business combinations and dividends, which limitations collectively are less restrictive than the terms of the bank Credit Agreement. CREDIT AGREEMENT In July 1993, the Company and certain of its subsidiaries entered into a new two-year bank Credit Agreement (Credit Agreement), which provides a $100 million facility for letters of credit or for direct borrowings of up to $25 million, with such borrowings being subject to an annual 20-day cleanup period. Interest on borrowings is based upon, at the Company's option, (i) the agent bank's prime rate plus 1/2% per annum; (ii) various Eurodollar related rates; and (iii) various certificate of deposit related rates. A fee of 1% per annum is payable quarterly on the outstanding balance of all letters of credit, and a commitment fee of 3/8 of 1% per annum is payable on the unused portion of the facility. The borrowing base for the facility consists of cash, cash equivalents, accounts receivable and inventory, all of which secure the facility. The Credit Agreement imposes certain restrictions, including: (i) a prohibition of other indebtedness in excess of $3 million with exceptions for, among other things, indebtedness under the Company's Senior Notes and certain nonrecourse debt; (ii) maintenance of certain levels of net worth, working capital and interest coverage; (iii) limitations on investments and dividends; and (iv) a prohibition of incursions on controlling ownership, material changes in senior management and business combinations with unaffiliated entities. At July 31, 1994, the Company had outstanding letters of credit totalling $51,376,000 and no borrowings. The unused commitment under the Credit Agreement at July 31, 1994 was $48,624,000, of which up to $25,000,000 may be used for additional direct borrowings. F-9 45 HOLLY CORPORATION NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED) JULY 31, 1994, 1993 AND 1992 The average and maximum amounts outstanding and the effective average interest rate for borrowings under the Company's current and prior credit agreements were as follows:
1994 1993 1992 ------- -------- -------- ($ IN THOUSANDS) Average amount outstanding............................. $ 39 $ 3,565 $ 7,558 Maximum balance........................................ $ 1,900 $ 22,330 $ 23,100 Effective average interest rate........................ 6.6% 6.6% 7.7%
The Senior Notes and Credit Agreement restrict investments and distributions, including dividends, to an amount in the aggregate not to exceed 75% of cumulative consolidated net income (as defined). Under the most restrictive of these covenants, at July 31, 1994 approximately $20.7 million was available for the payment of dividends. Maturities of long-term debt for the next five fiscal years are as follows: 1995 -- $5,608,000; 1996 -- $14,275,000; 1997 -- $14,275,000; 1998 -- $14,275,000 and 1999 -- $8,675,000. The Company made interest payments of $8,744,000 in 1994, $9,058,000 in 1993 and $9,361,000 in 1992. Based on the borrowing rates that the Company believes would be available for replacement loans with similar terms and maturities of the debt of the Company now outstanding, the fair value of long-term debt including current maturities would be $79.3 million at July 31, 1994. 7. INCOME TAXES Effective August 1, 1992, the Company adopted SFAS No. 109 to account for income taxes (see Note 2). The statutory federal income tax rate applied to pre-tax book income reconciles to income tax expense as follows:
1994 1993 1992 ------- ------- ------- ($ IN THOUSANDS) Tax computed at statutory rate........................ $12,251 $11,521(1) $ 225 State income taxes, net of federal tax benefit........ 1,888 1,744 35 Adjustment of deferred tax provision relating to MRC (see Note 10)....................................... -- -- (2,579) Other................................................. 146 119 222 ------- ------- ------- $14,285 $13,384 $(2,097) ======= ======= =======
(1) Blended rate, as federal income tax rate changed effective January 1, 1993. Additionally, tax benefit of $56,000, $63,000 and $239,000 for dividends paid in fiscal 1994, 1993 and 1992, respectively, to the Company's Employee Stock Ownership Plan was directly credited to retained earnings. Operations of the corporation that was the sole limited partner of MRC prior to the acquisition of such corporation by the Company (See Note 10) resulted in unused net operating loss carryforwards of approximately $7,000,000, which are expected to be available to the Company to a limited extent each year through 2006 based on the income of such corporation. As of July 31, 1994, approximately $6,000,000 of these net operating loss carryforwards remain available to offset future income. For financial reporting purposes, any benefit of these net operating loss carryforwards is being offset against any contingent future payments relating to the acquisition of such corporation. F-10 46 HOLLY CORPORATION NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED) JULY 31, 1994, 1993 AND 1992 Deferred income taxes reflect the net tax effects of temporary differences between the carrying amounts of assets and liabilities for financial reporting purposes and the amount used for income tax purposes. The Company's deferred income tax assets and liabilities as of July 31, 1994 and 1993 are as follows:
1994 ----------------------------------- ASSETS LIABILITIES TOTAL ------ ----------- -------- ($ IN THOUSANDS) Deferred taxes Nondeductible employee benefits............................ $1,376 $ -- $ 1,376 Provision for future maintenance........................... 1,353 -- 1,353 Prepayments and other...................................... 1,339 (1,747) (408) ------ ----------- -------- Total current................................................ 4,068 (1,747) 2,321 Properties, plants and equipment (primarily tax in excess of book depreciation)................................... -- (16,038) (16,038) Intangible drilling costs.................................. -- (704) (704) Nondeductible oil and gas costs............................ 1,813 -- 1,813 Other...................................................... 152 (52) 100 ------ ----------- -------- Total noncurrent............................................. 1,965 (16,794) (14,829) ------ ----------- -------- 6,033 (18,541) (12,508) Valuation allowance.......................................... -- -- -- ------ ----------- -------- Total........................................................ $6,033 $ (18,541) $(12,508) ====== =========== ========
1993 ----------------------------------- ASSETS LIABILITIES TOTAL ------ ----------- -------- ($ IN THOUSANDS) Deferred taxes Nondeductible employee benefits............................ $1,107 $ -- $ 1,107 Provision for future maintenance........................... 2,477 -- 2,477 Prepayments and other...................................... 521 (1,639) (1,118) ------ ----------- -------- Total current................................................ 4,105 (1,639) 2,466 Properties, plants and equipment (primarily tax in excess of book depreciation)................................... -- (13,423) (13,423) Intangible drilling costs.................................. -- (375) (375) Nondeductible oil and gas costs............................ 1,173 -- 1,173 Other...................................................... 151 -- 151 ------ ----------- -------- Total noncurrent............................................. 1,324 (13,798) (12,474) ------ ----------- -------- 5,429 (15,437) (10,008) Valuation allowance.......................................... -- -- -- ------ ----------- -------- Total........................................................ $5,429 $ (15,437) $(10,008) ====== =========== ========
F-11 47 HOLLY CORPORATION NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED) JULY 31, 1994, 1993 AND 1992 The deferred income tax benefits for the 1992 fiscal year (prior to the adoption of SFAS No. 109) are as follows:
1992 ---------------- ($ IN THOUSANDS) Excess tax (book) depreciation........................................ $ 1,361 Provision for future maintenance...................................... (423) Adjustment of prior years' deferred tax provision relating to MRC (see Note 10)................................................... (1,483) Other................................................................. (586) ------------ $ (1,131) ============
The Company made income tax payments of $18,893,000 in 1994, $5,138,000 in 1993 and $2,503,000 in 1992. The Company's federal income tax returns have been examined by the Internal Revenue Service through 1990. 8. STOCKHOLDERS' EQUITY STOCK OPTIONS At July 1, 1994 and 1993, no stock options were outstanding and 751,500 shares of common stock were reserved for issuance under the Company's stock option plan. 9. EMPLOYEE BENEFIT PLANS PENSION PLANS The Company has non-contributory defined benefit retirement plans that cover substantially all employees. The Company's policy is to make contributions annually of not less than the minimum funding requirements of the Employee Retirement Income Security Act of 1974. Benefits are based on the employee's years of service and compensation. Pension expense includes the following components:
1994 1993 1992 ------- ------- ------- ($ IN THOUSANDS) Service cost -- benefits earned during the year....... $ 1,014 $ 1,124 $ 908 Interest cost on projected benefit obligations........ 1,603 1,711 1,557 Actual return on plan assets.......................... (841) (1,802) (2,110) Net amortization and deferral......................... (1,252) (379) 35 ------- ------- ------- Pension expense....................................... $ 524 $ 654 $ 390 ======= ======= =======
F-12 48 HOLLY CORPORATION NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED) JULY 31, 1994, 1993 AND 1992 The following table sets forth the funded status of the plans and amounts recognized in the consolidated balance sheet:
1994 1993 ------- ------- ($ IN THOUSANDS) Plan assets at fair value........................................ $23,256 $23,478 Actuarial present value of projected benefit obligations: Accumulated benefit obligations: Vested...................................................... 17,733 17,034 Unvested.................................................... 222 303 Provision for future salary increases.......................... 6,171 6,289 ------- ------- Projected benefit obligations.................................... 24,126 23,626 ------- ------- Plan assets less than projected benefit obligations.............. (870) (148) Unrecognized net loss............................................ 248 227 Unrecognized prior service cost.................................. 108 144 Unrecognized transition net asset................................ (1,435) (1,648) ------- ------- Accrued pension liability recognized in the consolidated balance sheet.......................................................... $(1,949) $(1,425) ======= =======
The principal actuarial assumptions were:
1994 1993 1992 ---- ---- ---- Discount rate................................................. 7.5% 7.5% 7.5% Rate of future compensation increases......................... 5% 5% 6% Expected long-term rate of return on assets................... 8.5% 8.5% 9%
Pension costs are determined using the assumptions as of the beginning of the year. The funded status is determined using the assumptions as of the end of the year. Approximately 52% of plan assets is invested in equity securities and 48% is invested in fixed income securities and other instruments at July 31, 1994. EMPLOYEE STOCK OWNERSHIP PLAN In December 1985, the Company established an Employee Stock Ownership Plan (ESOP). The ESOP is non-contributory and includes substantially all employees of the Company and its subsidiaries who meet certain length of service requirements and are not covered by a collective bargaining agreement. In 1985, the ESOP borrowed from the Company the $4,102,000 needed to purchase 1,500,000 shares of the Company's common stock. The loan is repayable in ten annual installments of $410,000 (subject to certain adjustments) commencing August 1, 1986 and bears interest at 12% per annum. The Company is obligated to make annual contributions sufficient to enable the ESOP to repay the loan with interest. The unearned compensation of $4,102,000 was recorded as a reduction of stockholders' equity and is being reduced as payments are made. Interest income earned on the note due from the ESOP is offset against an equal amount contributed to the ESOP by the Company. 10. MONTANA REFINING COMPANY, A PARTNERSHIP The Company acquired on July 31, 1992, the corporation that was the limited partner in MRC in connection with a settlement of litigation. The acquisition involved among other items contingent future payments of up to $189,000 per year over the period 1993 through 2005. F-13 49 HOLLY CORPORATION NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED) JULY 31, 1994, 1993 AND 1992 As a consequence of the acquisition of the limited partner in MRC, certain deferred taxes have been eliminated, resulting in a decrease for fiscal 1992 of $2,579,000 in the provision for income taxes, of which $1,483,000 relates to income taxes provided in prior years. 11. OTHER INCOME (EXPENSE) The amounts in other income (expense) relate principally to settlements. The 1993 fiscal year included income of $4,000,000 relating to a settlement with a common carrier pipeline concerning product pipeline distribution constraints. The 1992 fiscal year included a charge of $700,000 relating to a settlement of a lawsuit with the limited partner of MRC (see Note 10). 12. CONTINGENCIES In July 1993, the United States Department of Justice, acting on behalf of the United States Environmental Protection Agency (EPA), filed a complaint in the United States District Court for the District of New Mexico alleging that the Company's subsidiary, Navajo Refining Company, beginning in September 1990 and continuing until the present, had violated and continues to violate the Resource Conservation and Recovery Act (RCRA) and implementing regulations of the EPA by treating, storing and disposing of certain hazardous wastes without compliance with regulatory requirements. The complaint seeks a court order directing Navajo to comply with these regulatory standards and civil penalties for the alleged non-compliance. Navajo has answered the complaint, denying all the allegations of legal liability and asserting affirmative defenses. Only limited discovery has been conducted. The Company and Navajo have been contesting the Government's case as necessary and appropriate, while contemporaneously exploring the prospects for negotiated settlement. In this regard, a tentative resolution of a substantial portion of the litigation has been reached. Under this approach, the Company would close the existing evaporation ponds of its wastewater management system, at an approximate cost of $1 to $2 million, to be expended over a several year period. A reserve of $2 million was recorded in fiscal 1993, principally to provide for the cost of closing existing ponds. In such event, the Company would implement one of several alternatives to the existing wastewater treatment system. Depending upon which approach is utilized, the Company could incur capitalizable costs of an additional $5 to $10 million over the next several years. Assuming the Company consummates the settlement discussed above, the remaining aspect of the litigation would be the civil penalty which the Government seeks. While the amount of any such civil penalty cannot presently be ascertained, based upon the advice of counsel, it is not believed that any such penalty would have a materially adverse impact on the Company's financial position. The Company is a party to various other litigation and proceedings which it believes, based on advice of counsel, will not have a materially adverse impact on its financial condition of operations. 13. SIGNIFICANT CUSTOMERS Virtually all revenues were domestic revenues (including domestic sales for export to Mexico). Approximately $67,000,000 (12%) of the Company's revenues for fiscal 1994, $65,000,000 (10%) of revenues for fiscal 1993 and $67,000,000 (13%) for fiscal 1992 were from the sale of military jet fuel to the United States Government. Approximately $58,000,000 (11%) of the Company's revenues for fiscal 1994 were from the sale of gasoline to an affiliate of PEMEX (the government-owned energy company of Mexico). In addition to the United States Government and PEMEX, another refiner, which is a purchaser of gasoline and diesel for resale to retail customers, accounted for approximately $75,000,000 (12%) of the Company's F-14 50 HOLLY CORPORATION NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED) JULY 31, 1994, 1993 AND 1992 revenues in fiscal 1993 and $96,000,000 (19%) in fiscal 1992. While a loss of, or reduction in amounts purchased by, major purchasers that resell to retail customers could have an adverse effect on the Company, the Company believes that the impact of such a loss on the Company's results of operations should be limited because the Company's sales volume with respect to products whose end-users are retail customers is more dependent on the general retail demand in the Company's primary markets than on sales to any specific customer. 14. QUARTERLY INFORMATION (UNAUDITED) FINANCIAL DATA
FIRST SECOND THIRD FOURTH QUARTER QUARTER QUARTER QUARTER YEAR -------- -------- -------- -------- -------- ($ IN THOUSANDS, EXCEPT PER SHARE AMOUNTS) 1994 Revenues $135,518 $120,689 $143,934 $152,179 $552,320 Operating margin (net sales less cost of sales)................................. $ 22,570 $ 15,790 $ 23,420 $ 8,207 $ 69,987 Income (loss) before income taxes......... $ 13,835 $ 7,134 $ 14,635 $ (602) $ 35,002 Net income (loss)......................... $ 8,273 $ 4,266 $ 8,730 $ (552) $ 20,717 Income (loss) per common share............ $ 1.00 $ .52 $ 1.06 $ (.07) $ 2.51 Dividends per share....................... $ .075 $ .075 $ .10 $ .10 $ .35 Average number of shares of common stock outstanding (in thousands)............. 8,254 8,254 8,254 8,254 8,254 1993 Revenues.................................. $151,910 $149,871 $161,695 $167,145 $630,621 Operating margin (net sales less cost of sales)................................. $ 12,296 $ 11,683 $ 16,783 $ 23,484 $ 64,246 Income before income taxes and cumulative effect of change in accounting for income taxes........................... $ 4,209 $ 2,830 $ 7,729 $ 18,549 $ 33,317 Income before cumulative effect of change in accounting principle................ $ 2,556 $ 2,052 $ 4,693 $ 10,632 $ 19,933 Cumulative effect to August 1, 1992 of change in accounting for income taxes.................................. (958) -- -- -- (958) -------- -------- -------- -------- -------- Net income............................. $ 1,598 $ 2,052 $ 4,693 $ 10,632(1) $ 18,975 ======== ======== ======== ======== ======== Income per common share Income before cumulative effect of change in accounting principle....... $ .31 $ .25 $ .57 $ 1.29 $ 2.42 Cumulative effect to August 1, 1992 of change in accounting for income taxes................................ (.12) -- -- -- (.12) -------- -------- -------- -------- -------- Net income............................. $ .19 $ .25 $ .57 $ 1.29 $ 2.30 ======== ======== ======== ======== ======== Dividends per share....................... $ .075 $ .075 $ .075 $ .075 $ .30 Average number of shares of common stock outstanding (in thousands)............. 8,254 8,254 8,254 8,254 8,254
(1) Includes pre-tax income of $4 million relating to a settlement and a pre-tax reserve of $2 million relating to EPA litigation (see Notes 11 and 12). F-15 51 HOLLY CORPORATION NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED) JULY 31, 1994, 1993 AND 1992 OPERATING DATA
FIRST SECOND THIRD FOURTH QUARTER QUARTER QUARTER QUARTER YEAR ------- ------- ------- ------- ------- (BARRELS PER DAY) 1994 Sales of refined products.............. 58,500 62,300 73,100 69,600 65,800 Refinery production.................... 54,100 66,000 69,900 67,500 64,300 1993 Sales of refined products.............. 63,400 66,100 70,700 70,900 67,800 Refinery production.................... 60,600 69,000 66,500 65,200 65,300
F-16 52 HOLLY CORPORATION CONDENSED CONSOLIDATED BALANCE SHEET ($ IN THOUSANDS, EXCEPT PER SHARE AMOUNTS)
UNAUDITED APRIL 30, 1995 ---------- ASSETS Current assets Cash and cash equivalents....................................................... $ 16,940 Accounts receivable: Trade...................................................... 39,742 Crude oil................................................ 46,386 ---------- 86,128 Inventories: Crude oil and refined products..................................... 33,631 Materials and supplies............................................. 6,349 ---------- 39,980 Income taxes receivable......................................................... 3,822 Prepayments and other........................................................... 9,435 ---------- Total current assets.................................................... 156,305 Properties, plants and equipment, at cost......................................... 245,713 Less accumulated depreciation, depletion and amortization......................... 115,778 ---------- 129,935 Other assets...................................................................... 4,193 ---------- $ 290,433 ========== LIABILITIES AND STOCKHOLDERS' EQUITY Current liabilities Accounts payable................................................................ $ 106,935 Accrued liabilities............................................................. 14,763 Income taxes payable............................................................ 625 Current maturities of long-term debt............................................ 5,608 ---------- Total current liabilities............................................... 127,931 Deferred income taxes............................................................. 17,371 Long-term debt, less current maturities........................................... 68,832 Contingencies Stockholders' equity Preferred stock, $1.00 par value -- 1,000,000 shares authorized; none issued.................................................................. -- Common stock, $.01 par value -- 20,000,000 shares authorized; 8,650,282 shares issued...................................................... 87 Additional capital.............................................................. 6,132 Retained earnings............................................................... 71,059 ---------- 77,278 Common stock held in treasury, at cost -- 396,768 shares........................ (569) Deferred charge -- amount due from ESOP......................................... (410) ---------- Total stockholders' equity.............................................. 76,299 ---------- $ 290,433 ==========
See accompanying notes to Condensed Consolidated Financial Statements. F-17 53 HOLLY CORPORATION CONDENSED CONSOLIDATED STATEMENT OF INCOME
UNAUDITED NINE MONTHS ENDED APRIL 30, --------------------- 1995 1994 -------- -------- ($ IN THOUSANDS EXCEPT PER SHARE AMOUNTS) Revenues: Net sales............................................................ $453,786 $399,701 Miscellaneous........................................................ 947 440 -------- -------- 454,733 400,141 Costs and expenses: Cost of sales........................................................ 412,322 337,921 General and administrative........................................... 9,629 9,153 Depreciation, depletion and amortization............................. 11,735 8,051 Exploration expenses, including dry holes............................ 2,451 2,706 Miscellaneous........................................................ 107 158 -------- -------- 436,244 357,989 -------- -------- Income from operations................................................. 18,489 42,152 Other: Interest income...................................................... 732 254 Interest expense..................................................... (6,337) (6,802) -------- -------- (5,605) (6,548) -------- -------- Income before income taxes and cumulative effect of change in accounting for turnarounds................................. 12,884 35,604 Income tax provision: Current.............................................................. 3,586 12,416 Deferred............................................................. 1,439 1,919 -------- -------- 5,025 14,335 -------- -------- Income before cumulative effect of change in accounting method......... 7,859 21,269 Cumulative effect to August 1, 1994 of change in accounting for turnarounds, net of taxes......................................................... 5,703 -- -------- -------- Net income............................................................. $ 13,562 $ 21,269 ======== ======== Income per common share: Income before cumulative effect of change in accounting method....... $ .95 $ 2.58 Cumulative effect to August 1, 1994 of change in accounting for turnarounds, net of taxes......................................... .69 -- -------- -------- Net income........................................................... $ 1.64 $ 2.58 ======== ======== Cash dividends paid per share.......................................... $ 30 $ .25 Average number of shares of common stock outstanding (in thousands).... 8,254 8,254
See accompanying notes to Condensed Consolidated Financial Statements. F-18 54 HOLLY CORPORATION CONDENSED CONSOLIDATED STATEMENT OF CASH FLOWS
UNAUDITED NINE MONTHS ENDED APRIL 30, --------------------- 1995 1994 -------- -------- ($ IN THOUSANDS) Cash flows from operating activities: Net income........................................................... $ 13,562 $ 21,269 Adjustments to reconcile net income to net cash provided by operating activities: Depreciation, depletion and amortization........................ 11,735 8,051 Deferred income taxes........................................... 1,439 1,919 Dry hole costs and leasehold impairment......................... 652 1,037 Cumulative effect to August 1, 1994 of change in accounting for turnarounds.............................................. (5,703) -- Changes in other assets and liabilities: (Increase) decrease in accounts receivable................... 8,152 (1,282) Decrease in inventories...................................... 4,015 869 Increase in income taxes receivable.......................... (3,094) -- (Increase) decrease in prepayments and other................. 1,458 (614) Increase (decrease) in accounts payable...................... (5,149) 21 Increase (decrease) in accrued liabilities................... 2,473 (1,566) Decrease in income taxes payable............................. (111) (2,452) Other, net...................................................... (2,696) 630 -------- -------- Net cash provided by operating activities......................... 26,733 27,882 Cash flows from financing activities: Reduction in long-term debt.......................................... (8) (8) Cash dividends....................................................... (2,476) (2,063) -------- -------- Net cash used for financing activities............................ (2,484) (2,071) Cash flows from investing activities: Additions to properties, plants and equipment........................ (10,606) (18,505) -------- -------- Net cash used for investing activities............................ (10,606) (18,505) -------- -------- Cash and cash equivalents: Increase for the period.............................................. 13,643 7,306 Beginning of year.................................................... 3,297 6,631 -------- -------- End of period........................................................ $ 16,940 $ 13,937 ======== ======== Supplemental disclosure of cash flow information: Cash paid during period for: Interest.......................................................... $ 4,249 $ 4,569 Income taxes...................................................... $ 6,744 $ 14,752
See accompanying notes to Condensed Consolidated Financial Statements. F-19 55 HOLLY CORPORATION NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS NOTE A -- PRESENTATION OF FINANCIAL STATEMENTS In the opinion of the Company, the accompanying consolidated financial statements, which have not been audited by independent accountants (except for the consolidated balance sheet as of July 31, 1994), reflect all adjustments (consisting only of normal recurring adjustments, except for the accounting change as described in Note B below) necessary to present fairly the Company's consolidated financial position as of April 30, 1995, the consolidated results of operations for the nine months ended April 30, 1995 and 1994, and consolidated cash flows for the nine months ended April 30, 1995 and 1994. Certain notes and other information have been condensed or omitted. Therefore, these financial statements should be read in conjunction with the consolidated financial statements and related notes included in the Company's Annual Report on Form 10-K for the fiscal year ended July 31, 1994. References herein to the "Company" are for convenience of presentation and may include obligations, commitments or contingencies that pertain solely to one or more affiliates of the Company. Results of operations for the first nine months of fiscal 1995 are not necessarily indicative of the results to be expected for the full year. NOTE B -- ACCOUNTING CHANGE Effective August 1, 1994, the Company changed its method of accounting for turnaround costs. Turnarounds consist of preventive maintenance on major processing units as well as the shutdown and restart of all units, and generally are scheduled at two to three year intervals. Previously, the Company estimated the costs of the next scheduled turnaround and ratably accrued the related expenses prior to the actual turnaround. To provide for a better matching of turnaround costs with revenues, the Company changed its accounting method for turnaround costs to one that results in the amortization of costs incurred over the period until the next scheduled turnaround. The cumulative effect of this accounting change through the 1994 fiscal year was an increase in net income in the current year of $5,703,000, or $.69 per common share. Excluding the cumulative effect, the change increased net income for the nine months ended April 30, 1995 by $950,000 or $.12 per common share. If the accounting change for turnaround costs had been retroactively applied, pro forma net income for the nine months ended April 30, 1994 would have increased by $1,162,000 or $.14 per share over what was originally reported and net income for the full 1994 fiscal year would have increased by $1,266,000 or $.15 per share to pro forma net income amounts for the 1994 fiscal year of $21,983,000 or $2.66 per share. NOTE C -- CONTINGENCIES In July 1993, the DOJ filed suit against Navajo alleging that, beginning in September 1990 and continuing through the present, Navajo has violated and continues to violate RCRA and implementing regulations of the EPA by treating, storing and disposing of certain hazardous wastes without compliance with regulatory requirements. The Company believes that the parties are in the final stage of negotiating a resolution of the litigation. If settled as anticipated, the Company would close the existing evaporation ponds of its wastewater management system at a cost believed to be substantially less than $1 million. The settlement also contemplates that the Company would implement one of several alternatives to the existing wastewater treatment system. Depending upon which approach is utilized, the Company could incur total costs of approximately $3 million over the next several years. The costs to implement an alternative wastewater treatment system would be capitalized and amortized over the future useful life of the resulting asset in accordance with generally accepted accounting principles. The settlement with the DOJ also is expected to involve the payment of a civil penalty of less than $2 million. In fiscal 1993, the Company recorded a $2 million reserve for the litigation. F-20 56 HOLLY CORPORATION NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS -- CONTINUED NOTE D -- SUBSEQUENT EVENT The Company filed a Form S-3 Registration Statement on May 17, 1995 relating to the sale of up to 2,500,000 shares of common stock (before an over-allotment option of up to 375,000 shares granted to the underwriters for such offering by certain selling stockholders (the "Selling Stockholders")). Of those shares, 1,500,000 shares will be sold by the Company and 1,000,000 shares (plus up to 375,000 shares subject to the over-allotment option) will be sold by the Selling Stockholders. The Company will not receive any portion of the proceeds from the sale of shares of common stock by the Selling Stockholders. The Company will use $15 million of the net offering proceeds to pay for certain capital improvements to enhance its Navajo Refinery, located in New Mexico. It will use the balance of the net offering proceeds, together with internally generated funds, for other capital improvement projects currently being evaluated and/or for general corporate purposes. F-21 57 - -------------------------------------------------------------------------------- - -------------------------------------------------------------------------------- NO DEALER, SALESPERSON OR OTHER INDIVIDUAL HAS BEEN AUTHORIZED TO GIVE ANY INFORMATION OR TO MAKE ANY REPRESENTATIONS NOT CONTAINED IN, OR INCORPORATED BY REFERENCE IN, THIS PROSPECTUS, IN CONNECTION WITH THE OFFERING COVERED BY THIS PROSPECTUS. IF GIVEN OR MADE, SUCH INFORMATION OR REPRESENTATIONS MUST NOT BE RELIED UPON AS HAVING BEEN AUTHORIZED BY THE COMPANY, THE SELLING STOCKHOLDERS OR THE UNDERWRITERS. THIS PROSPECTUS DOES NOT CONSTITUTE AN OFFER TO SELL, OR A SOLICITATION OF AN OFFER TO BUY, THE COMMON STOCK IN ANY JURISDICTION WHERE, OR TO ANY PERSON TO WHOM, IT IS UNLAWFUL TO MAKE SUCH OFFER OR SOLICITATION. NEITHER THE DELIVERY OF THIS PROSPECTUS NOR ANY SALE MADE HEREUNDER SHALL, UNDER ANY CIRCUMSTANCES, CREATE AN IMPLICATION THAT THERE HAS NOT BEEN ANY CHANGE IN THE FACTS SET FORTH IN THIS PROSPECTUS OR INCORPORATED BY REFERENCE HEREIN OR IN THE AFFAIRS OF THE COMPANY SINCE THE DATE HEREOF. ------------------------ TABLE OF CONTENTS
PAGE ---- Available Information................. 3 Incorporation of Certain Documents by Reference........................... 3 Prospectus Summary.................... 4 Risk Factors.......................... 9 Use of Proceeds....................... 12 Capital Improvement Projects.......... 12 Capitalization........................ 13 Price Range of Common Stock and Dividend Policy..................... 14 Selected Financial Data............... 15 Management's Discussion and Analysis of Results of Operations and Financial Condition................. 17 Business.............................. 22 Management and Directors.............. 31 Selling Stockholders.................. 33 Description of Common Stock........... 34 Underwriting.......................... 34 Legal Matters......................... 35 Experts............................... 35 Index to Consolidated Financial Statements.......................... F-1
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