hollycorp.annualreport.1999

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hollycorp.annualreport.1999

  1. 1. 1999 ANNUAL REPORT
  2. 2. HOLLY CORPORATION THROUGH ITS AFFILIATES, NAVAJO REFINING COMPANY AND MONTANA REFINING COMPANY, IS ENGAGED IN THE REFINING, TRANSPORTATION, TERMINALLING AND MARKETING OF PETROLEUM PRODUCTS.
  3. 3. HOLLY CORPORATION 1 FINANCIAL AND OPERATING HIGHLIGHTS Years ended July 31, 1999 1998 1997 Sales and other revenues............................................. $ 597,986,000 $ 590,299,000 $ 721,346,000 Income before income taxes....................................... $ 33,159,000 $ 24,866,000 $ 21,819,000 Net income ................................................................. $ 19,937,000 $ 15,167,000 $ 13,087,000 Net income per common share (basic and diluted).... $ 2.42 $ 1.84 $ 1.59 Net cash provided by operating activities ................... $ 47,628,000 $ 38,193,000 $ 5,457,000 Capital expenditures ................................................... $ 26,903,000 $ 49,715,000 $ 30,304,000 Total assets .................................................................. $ 390,982,000 $ 349,857,000 $ 349,803,000 Working capital........................................................... $ 13,851,000 $ 14,793,000 $ 45,241,000 Long-term debt (including current portion)................. $ 70,341,000 $ 75,516,000 $ 86,291,000 Stockholders’ equity.................................................... $ 128,880,000 $ 114,349,000 $ 105,121,000 Employees ................................................................... 614 588 572 CONTENTS Financial and Operating Highlights ........................... 1 Letter to Stockholders ................................................ 2 Selected Financial and Operating Data...................... 8 Market Information .................................................... 8 Management’s Discussion and Analysis of Financial Condition and Results of Operations ........ 9 Report of Independent Auditors ................................. 17 Consolidated Financial Statements............................. 18 Notes to Consolidated Financial Statements .............. 22 Board of Directors ..................................................... 32 Officers and Corporate Data...................................... 33 This Annual Report contains statements with respect to the Company’s expectations or beliefs as to future events. These types of statements are “forward-looking” and are subject to uncertainties. See “Factors Affecting Forward-Looking Statements” on page 9.
  4. 4. HOLLY CORPORATION 2 TO OUR STOCKHOLDERS The fiscal year just concluded marked another year of increased earnings and the highest such level since 1994. In conjunction with efforts to control outlays, cash flow increased sharply and your Company’s financial condition strengthened. Net income of the Company increased from $15.2 million in 1998 to $19.9 million in fiscal 1999. The SALES AND OTHER REVENUES (millions of dollars) 721 676 615 590 598 95 96 97 98 99 The Company’s Navajo Refinery in Artesia, New Mexico converts approximately 90% of its raw materials into high value refined products and serves markets in the southwestern United States and northern Mexico.
  5. 5. HOLLY CORPORATION 3 increase in income was driven by increased profitability at the Navajo Refinery as well as increased contributions from our transportation business. Refining results benefited from strong margins during the latter part of the fiscal year and the full effects of process improvements implemented at the Navajo Refinery during 1998. Significant growth in transportation business activities provided increased earnings for this segment over the prior year. The cornerstones for growth in our transportation business division have been an expansion of the Navajo Refinery’s supply and distribution network together with NET INCOME (millions of dollars) development and participation in transportation ventures (includes accounting change) with other companies. Within the last three years, your Company has more than doubled its pipeline network from approximately 1,000 miles to 2,000 miles through a combination of lease and purchase transactions and new 20 construction. We hope to continue growing this business 19 over the next several years. 18 One of the major elements of growth in our transportation business has been the operation of a West 15 Texas crude oil gathering system, which the Company acquired in 1998. This system provides transportation 13 revenues as well as a source of supply for the Navajo Refinery. During 1997, we also formed an alliance between Navajo Refining Company and Fina, Inc., which has resulted in a gasoline and diesel supply network for the growing markets of West Texas, Arizona and New Mexico. Under this agreement, Fina utilizes a Company pipeline to transport refined products from its West Texas refinery to El Paso. Holly began realizing both pipeline and terminalling revenues under this arrangement during fiscal 1999. 95 96 97 98 99 During 1999, we completed construction of a 65-mile pipeline between Lovington and Artesia, New Mexico. Completion of this line allowed Navajo to provide transportation of LPGs for other companies as well as enhance its raw material supply capabilities. This year was another successful year for our Rio Grande Pipeline joint venture. This joint venture, in which we own a 25% interest with Mid-America Pipeline Company and BP Amoco, provides pipeline transportation of LPGs to Mexico. An expansion of this pipeline’s capacity, currently under discussion, will provide the opportunity for further growth in earnings. Unfortunately, the market price of Holly shares has not reflected this strong growth in our transportation business and our improved financial performance at the Navajo Refinery. While we don’t profess to understand the
  6. 6. HOLLY CORPORATION 4 CAPITAL EXPENDITURES (millions of dollars) 50 30 27 18 15 movement of markets, many observers relate the depressed 95 96 97 98 99 share price to the continued existence of the Longhorn Partners Pipeline, L.P. lawsuit. As you may remember, this suit was filed against us in August 1998 and alleges damages in excess of one billion dollars. Preliminary REFINERY PRODUCTION procedures on this case consumed most of the last 12 (thousand barrels per day) months, and there is no timetable yet for final adjudication. In our judgment, this lawsuit has no merit whatsoever. In fact, we believe that the suit’s lack of merit is more obvious after the preliminary results, just released, of a federal 71 69 environmental assessment on the Longhorn Pipeline. The 68 68 draft report concludes that the Longhorn Pipeline would 62 have potential for significant adverse environmental impact unless a proposed 34-part remediation plan is carried out. While we remain sensitive to the decline in our share price and intend to pursue efforts to increase operating cash flow in the hopes of near-term improvement, we remain committed to a vigorous defense of the lawsuit and ultimate vindication for the Company. Finally, there were some significant organizational changes during the year. Two of our most senior executives, Jack Reid, Executive Vice President, Refining, and Bill Gray, Senior Vice President, Marketing and Supply, have chosen to retire after many years of dedicated service. In light of these changes, Matt Clifton has assumed additional responsibilities as President of Navajo Refining Company. While Jack’s and Bill’s contributions will be sorely missed, 95 96 97 98 99 they have both agreed to serve as consultants to the Company and to remain on the Board of Directors. On behalf of the Board of Directors, employees, suppliers,
  7. 7. HOLLY CORPORATION 5 The Company’s STOCKHOLDERSÕ EQUITY Montana Refinery (millions of dollars) near Great Falls, 129 Montana can process a wide 114 range of crude oils 105 and serves markets primarily in 96 Montana. 80 customers and ourselves, we wish to thank Jack and Bill for 95 96 97 98 99 their many years of service and significant contributions to the success of the Company. We also had an increase in the membership of our Board this year. W. John Glancy, Senior Vice President, NET CASH PROVIDED BY General Counsel and Secretary, was elected in September OPERATING ACTIVITIES 1999. John has been associated with Holly in a variety of (millions of dollars) capacities over more than 25 years and we look forward to his continuing contributions. In closing, we would like to express once again our 48 thanks to you for your continued confidence and support. 44 Sincerely, 38 34 Lamar Norsworthy Chairman of the Board and Chief Executive Officer 5 Matthew P. Clifton President 95 96 97 98 99 October 28, 1999
  8. 8. HOLLY CORPORATION 6 JACK P. REID AND WILLIAM J. GRAY RETIRE NAVAJO REFINING COMPANY 1999 Sales of Refinery Produced Products 63,700 bpd 4% LPG & OTHERS 2,400 5% ASPHALTS 3,600 DIESEL FUELS 13,400 21% GASOLINE 37,400 59% 11% JET FUELS 6,900 Jack P. Reid (sitting), Holly Corporation’s former Executive Vice President, Refining and President of Navajo Refining Company, retired effective August 1, 1999. Jack has played a key leadership role in MONTANA REFINING COMPANY Navajo Refining Company for the last thirty years. 1999 Sales of Refinery Produced Products The Company will always be grateful for his 6,700 bpd leadership and unmatched dedication and loyalty to LPG & OTHERS 300 5% Navajo Refining Company, its employees, and its community. 25% ASPHALTS 1,700 William J. Gray (standing), formerly Holly GASOLINE 2,800 42% Corporation’s Senior Vice President, Marketing and Supply, and Senior Vice President of Navajo DIESEL FUELS 1,500 22% Refining Company, retired effective October 1, JET FUELS 400 6% 1999. Bill’s contributions throughout his thirty-year career in leading the Company’s marketing and pipeline activities have been important to the success of the Company. His great sense of humor and sincere caring for the Company’s employees and the community made Navajo Refinery and Artesia, New Mexico better places to work and live. Both Jack and Bill will continue to serve as members of Holly’s Board of Directors. We thank Jack and Bill for their many years of fine service to the Company and wish each of them a happy retirement.
  9. 9. HOLLY CORPORATION 7 MONTANA REFINING COMPANY REFINERIES/TERMINALS TERMINALS COMPANY OWNED PRODUCT PIPELINES COMMON CARRIER PRODUCT PIPELINES LEASED PRODUCT PIPELINE JOINT VENTURE LPG PIPELINE PLANNED TERMINAL NAVAJO REFINING COMPANY
  10. 10. HOLLY CORPORATION 8 SELECTED FINANCIAL AND OPERATING DATA ($ in thousands, except per share amounts) Years ended July 31, 1999 1998 1997 1996 1995 FINANCIAL DATA For the year Sales and other revenues........................................................ $ 597,986 $ 590,299 $ 721,346 $ 676,290 $ 614,830 Income before income taxes and cumulative effect of accounting change ............................................. $ 33,159 $ 24,866 $ 21,819 $ 31,788 $ 20,147 Income tax provision.............................................................. 13,222 9,699 8,732 12,554 7,730 ------------------------------------ ------------------------------------ -------------------------------------- ------------------------------------ ------------------------------------ Income before cumulative effect of accounting change ........ 19,937 15,167 13,087 19,234 12,417 Cumulative effect of accounting change................................ – – – – 5,703 ------------------------------------ ------------------------------------ -------------------------------------- ------------------------------------ ------------------------------------ Net income ............................................................................ .$......19,937. .$................. . 15,167 .$.................. . 13,087 .$......19,234. .$......18,120. . .......... . .......... . .......... Income per common share Income before cumulative effect of accounting change (basic and diluted)................... $ 2.42 $ 1.84 $ 1.59 $ 2.33 $ 1.51 Cumulative effect of accounting change.......................... – – – – .69 ------------------------------------ ------------------------------------ -------------------------------------- ------------------------------------ ------------------------------------ Net income (basic and diluted)........................................ .$..........2.42. .$................. .$.................. . 1.84 . 1.59 .$..........2.33. .$..........2.20. . ...... . ...... . ...... Cash dividends per common share........................................ $ .64 $ .60 $ .51 $ .42 $ .40 Average number of shares of common stock outstanding...... 8,254,000 8,254,000 8,254,000 8,254,000 8,254,000 Net cash provided by operating activities .............................. $ 47,628 $ 38,193 $ 5,457 $ 44,452 $ 34,241 At end of year Working capital...................................................................... $ 13,851 $ 14,793 $ 45,241 $ 66,649 $ 17,740 Total assets.............................................................................. $ 390,982 $ 349,857 $ 349,803 $ 351,271 $ 287,384 Long-term debt (including current portion)............................ $ 70,341 $ 75,516 $ 86,291 $ 97,065 $ 68,840 Stockholders’ equity ............................................................... $ 128,880 $ 114,349 $ 105,121 $ 96,243 $ 80,043 OPERATING DATA For the year Sales of refined products – barrels-per-day ............................ 75,400 67,700 69,300 70,300 69,800 Refinery production – barrels-per-day.................................... 70,700 61,800 68,600 68,400 68,100 MARKET INFORMATION The Company’s 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 sales prices per share of common stock, dividends paid per share and the trading volume of common stock for the periods indicated: Total Fiscal years ended July 31, High Low Dividends Volume 1998 First Quarter............................................................................................. $ 28 13/16 $ 25 13/16 $ .15 721,200 Second Quarter ....................................................................................... 28 24 7/8 .15 416,900 Third Quarter........................................................................................... 33 3/8 25 5/8 .15 871,500 Fourth Quarter......................................................................................... 31 3/4 24 1/8 .15 648,600 1999 First Quarter............................................................................................. $ 26 1/8 $ 14 3/8 $ .16 1,053,500 Second Quarter ....................................................................................... 17 3/8 14 .16 712,200 Third Quarter........................................................................................... 15 5/8 12 1/4 .16 1,043,700 Fourth Quarter......................................................................................... 15 3/4 12 5/8 .16 1,425,900 As of July 31, 1999, the Company had approximately 1,800 stockholders of record. On September 24, 1999, the Company’s Board of Directors declared a regular quarterly dividend in the amount of $.17 per share payable on October 8, 1999. The Company intends to consider the declaration of a dividend on a quarterly basis, although there is no assurance as to future dividends since they are dependent upon future earnings, capital requirements, the financial condition of the Company and other factors. The Senior Notes and Credit Agreement limit the payment of dividends. See Note 6 to the Consolidated Financial Statements.
  11. 11. HOLLY CORPORATION 9 MANAGEMENTÕS DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS FACTORS AFFECTING FORWARD- RESULTS OF OPERATIONS LOOKING STATEMENTS Financial Data This Annual Report contains certain “forward-looking Years Ended July 31, ($ in thousands, statements” within the meaning of the U.S. Private except per share data) (1) 1999 1998 1997 Sales and other revenues ......... $597,986 $590,299 $721,346 Securities Litigation Reform Act of 1995. All statements, Costs and expenses other than statements of historical facts included in this Cost of products sold............ 428,472 440,042 586,604 Annual Report, including without limitation those under Operating expenses.............. 80,654 76,420 70,009 “Liquidity and Capital Resources” and “Additional Selling, general and Factors that May Affect Future Results” under this administrative expenses..... 22,159 13,714 13,348 “Managemen’s Discussion and Analysis of Financial Depreciation, depletion Condition and Results of Operations” regarding the and amortization............... 26,358 24,379 20,153 Company’s financial position and results of operations, Exploration expenses, are forward-looking statements. Such statements are including dry holes ........... 1,370 2,979 3,732 subject to risks and uncertainties, including but not ------------------------------- ------------------------------- ------------------------------- limited to risks and uncertainties with respect to the 559,013 557,534 693,846 ------------------------------- ------------------------------- ------------------------------- actions of actual or potential competitive suppliers of Income from operations........... 38,973 32,765 27,500 refined petroleum products in the Company’s markets, Other the demand for and supply of crude oil and refined Equity in earnings of products, the spread between market prices for refined joint ventures..................... 1,965 1,766 414 products and crude oil, the possibility of constraints on Interest expense, net............. (7,779) (7,725) (6,095) the transportation of refined products, the possibility of Transaction costs of inefficiencies or shutdowns in refinery operations or terminated merger............. – (1,940) – ------------------------------- ------------------------------- ------------------------------- pipelines, governmental regulations and policies, the (5,814) (7,899) (5,681) ------------------------------- ------------------------------- ------------------------------- availability and cost of financing to the Company, the Income before income taxes.... 33,159 24,866 21,819 effectiveness of capital investments and marketing Income tax provision ............... 13,222 9,699 8,732 ------------------------------- ------------------------------- ------------------------------- strategies by the Company, the costs of defense and the Net income.............................. $ 19,937 $ 15,167 $ 13,087 ................ ................ ................ risk of an adverse decision in the Longhorn Pipeline Income per common share litigation, the accuracy of technical analysis and (basic and diluted) ................ $ 2.42 $ 1.84 $ 1.59 evaluations relating to the Year 2000 Problem, and the abilities of third-party suppliers to the Company to avoid Sales and other revenues (2) adverse effects of the Year 2000 Problem on their Refining ................................ $582,172 $582,277 $715,023 capacities to supply the Company. Should one or more Pipeline Transportation ......... 11,936 695 – of these risks or uncertainties, among others as set forth Corporate and other ............. 3,878 7,327 6,323 ------------------------------- ------------------------------- ------------------------------- in this Annual Report or in the Form 10-K Annual Report Consolidated......................... $597,986 $590,299 $721,346 ................ ................ ................ for the fiscal year ended July 31, 1999, materialize, actual results may vary materially from those estimated, Income (loss) from operations (2) anticipated or projected. Although the Company believes Refining ................................ $ 42,118 $ 38,290 $ 33,877 that the expectations reflected by such forward-looking Pipeline Transportation ........ 6,552 302 – statements are reasonable based on information currently Corporate and other ............. (9,697) (5,827) (6,377) ------------------------------- ------------------------------- ------------------------------- available to the Company, no assurances can be given Consolidated......................... $ 38,973 $ 32,765 $ 27,500 ................ ................ ................ that such expectations will prove to have been correct. 1) Certain reclassifications have been made to prior reported amounts to conform to Cautionary statements identifying important factors that current classifications. could cause actual results to differ materially from the 2) The Refining segment includes the Company’s principal refinery in Artesia, New Mexico, which is operated in conjunction with refining facilities in Lovington, New Company’s expectations are set forth in this Annual Mexico (collectively, the Navajo Refinery) and the Company’s refinery near Great Falls, Report and in the Form 10-K Annual Report for the fiscal Montana. The petroleum products produced by Refining segments are marketed in the southwestern United States, Montana and northern Mexico. Certain pipelines and year ended July 31, 1999, including without limitation in terminals operate in conjunction with the Refining segment as part of the supply and conjunction with the forward-looking statements distribution networks of the refineries, which costs are included in the Refining segment. The Pipeline Transportation segment includes approximately 900 miles of the Company’s included in this Annual Report that are referred to above. pipeline assets in Texas and New Mexico. Revenues from the Pipeline Transportation All forward-looking statements included in this Annual segment are earned through transactions with unaffiliated parties for pipeline transportation, rental and terminalling operations. Included in Corporate and other are Report and all subsequent written or oral forward-looking costs associated with Holly Corporation, the parent company, consisting primarily of statements attributable to the Company or persons acting general and administrative expenses and interest charges, as well as a small-scale oil and gas exploration and production program and a small equity investment in retail gasoline on its behalf are expressly qualified in their entirety by stations and convenience stores. Insignificant amounts of intersegment sales were these cautionary statements. eliminated in consolidation.
  12. 12. HOLLY CORPORATION 10 Operating Data and gas income due to decreased prices for oil and gas and a reduction in scope of the Company’s oil and gas Years Ended July 31, program, and increases in depreciation and amortization 1999 1998 1997 Refinery Production (BPD)....... 70,700 61,800 68,600 expenses resulting primarily from the prior year’s Sales of Refined turnaround expenditures and the increase in pipeline Products (BPD) (1) .................. 75,400 67,700 69,300 transportation operations. Refinery Margins (per produced barrel sold) .... $ 5.91 $ 6.09 $ 5.18 1998 Compared to 1997 For the 1998 fiscal year, net income was $15.2 1) Includes refined products purchased for resale of 5,000 BPD, 4,600 BPD and million ($1.84 per share) as compared to $13.1 million 2,200 BPD, respectively, for the years shown in the above table. ($1.59 per share) for fiscal 1997. Transaction costs 1999 Compared to 1998 associated with the planned merger with Giant For the year ended July 31, 1999, net income was Industries, Inc., which was terminated, reduced earnings $19.9 million ($2.42 per share), as compared to $15.2 by $1.2 million ($.14 per share) for the 1998 fiscal year. million ($1.84 per share) for fiscal 1998. The increase in The increase in income in the 1998 fiscal year net income for fiscal 1999 was primarily attributable to compared to 1997 was principally due to increased increased refined product sales volumes and increased refinery margins of 17.6%. Refined product revenues pipeline transportation income, partially offset by lower decreased in the year ended July 31, 1998 from the prior refinery margins and increased selling, general and year as a result of reduced sales prices and reduced administrative expenses. overall sales volumes for the 1998 fiscal year, due Refinery margins decreased 3.0% during fiscal 1999 principally to decreased production at the Navajo compared to the prior year, as product prices decreased Refinery. Refinery margins increased significantly during at a slightly greater rate than crude prices. However, the the fourth quarter of fiscal 1998 as crude oil prices Company experienced higher refinery margins in April decreased at a faster rate than refined product prices in through July 1999 as product prices increased at a the Company’s markets. However, a 9.9% reduction in greater rate than crude prices in the California refined production of refined products partially offset the year- products market, which impacts product pricing for the over-year refinery margin increases. Company’s Navajo Refinery in New Mexico. Such The reduced production for the 1998 fiscal year margins have declined since that time. Increased resulted from a planned maintenance shutdown (a production volumes of 14.4% for fiscal 1999 more than “turnaround”) at the Company’s Navajo Refinery. The offset the reduced margins, compared to fiscal 1998, turnaround, which is scheduled approximately every four when such volumes were reduced due to a turnaround at years, was conducted in the first quarter and early part of the Navajo Refinery. Refined product revenues did not the second quarter of fiscal 1998. This turnaround change significantly as the decrease in product prices included an upgrade of the fluid catalytic cracking unit was offset by the increase in sales volumes, due (“FCC”) to more efficient technology. The effects of this principally to the increased production at the Navajo upgrade, combined with the effects of the isomerization Refinery. Refining operating expenses were relatively unit which became operational at the end of the prior constant from year-to-year. fiscal year, have substantially improved the high value Pipeline Transportation revenues increased product yields of the Navajo facility. The increase in significantly as the result of the initiation of pipeline and these yields contributed favorably to refinery margins terminalling related revenues under agreements with beginning in the second quarter of fiscal 1998. Earnings FINA, Inc. and from operation of a West Texas crude oil in fiscal 1998 were adversely impacted by an increase in gathering system the Company purchased in June 1998. depreciation, depletion and amortization resulting from Additionally, the Company began generating the amortization of higher turnaround costs beginning in transportation revenues in June 1999 from deliveries of the second quarter. Additionally impacting earnings for isobutane to another refinery. Most of the increase in the 1998 fiscal year was the inclusion in operating operating expenses for the Company results from the expenses of costs associated with the lease of 300 miles increased pipeline transportation operations. of 8quot; pipeline which began late in the fourth quarter of Earnings were negatively impacted in the 1999 fiscal fiscal 1997. The Company plans to utilize this pipeline to year, as compared to the prior year, by an increase in transport petroleum products from the Navajo Refinery to general and administrative expenses relating principally markets in Albuquerque and northwest New Mexico to legal proceedings and non-recurring compensation during the 2000 fiscal year. Earnings for fiscal 1998 were expense, partially offset by charges in fiscal 1998 in also impacted by a decrease in interest income due to a connection with the terminated merger with Giant lower level of cash investments in fiscal 1998 as Industries, Inc. Additionally, earnings were impacted compared to fiscal 1997. during fiscal 1999 relative to fiscal 1998 by lower oil
  13. 13. HOLLY CORPORATION 11 LIQUIDITY AND CAPITAL RESOURCES capital expenditure requirements and dividend payments of $5.0 million more than offset higher cash flow from Cash and cash equivalents increased during the year operating activities, resulting in an outstanding balance ended July 31, 1999 by $1.6 million to $4.2 million, as of $11.6 million under the Credit Agreement. cash flows from operations were greater than capital The Company believes its internally generated cash expenditures, principal repayments, including the flow, along with its Credit Agreement, provides sufficient repayment of $11.6 million which represents all resources to fund capital projects, scheduled repayments outstanding borrowings under the Credit Agreement, and of the Senior Notes, continued payment of dividends dividend payments. Subsequent to July 31, 1999, the (although dividend payments must be approved by the Company has generated cash balances in excess of its Board of Directors and cannot be guaranteed) and the ongoing liquidity requirements. The Company believes Company’s liquidity needs for at least the next twelve that this cash, in conjunction with its Credit Agreement, months. The Company’s Credit Agreement expires in which can be used for direct borrowings of up to $50 October 2000, and the Company has recently initiated million and which will expire in October 2000 unless discussions with its banks on an extension of the Credit extended, together with future cash flows from Agreement. While the Company expects such operations, should provide sufficient resources to enable negotiations to result in the extension of the Credit the Company to satisfy its liquidity needs, capital Agreement, there can be no assurance that such requirements, and debt service obligations while negotiations will be successful. continuing the payment of dividends for at least the next See Note 6 to the Consolidated Financial Statements twelve months. for a summary of the terms and conditions of the Senior Notes and of the Credit Agreement. Cash Flows from Operating Activities Net cash provided by operating activities amounted Cash Flows for Investing Activities and Capital Projects to $47.6 million in fiscal 1999, compared to $38.2 Cash flows used for investing activities totalled million in fiscal 1998 and $5.5 million in fiscal 1997. $109.3 million over the last three years, $24.0 million in Comparing fiscal 1999 to fiscal 1998, the increase in 1999, $51.0 million in 1998 and $34.4 million in 1997. cash provided from operating activities was principally All of these amounts were expended on capital projects due to expenditures of $18.8 million incurred in fiscal with the exceptions of $2.0 million during fiscal 1998 1998 relating to the Navajo turnaround, offset partially invested in a joint venture to operate retail gasoline by changes in working capital items. Comparing fiscal stations and convenience stores in Montana, $3.0 million 1998 to fiscal 1997, cash provided from operating invested during 1998 in shares of common stock of a activities was significantly higher. The increase was publicly traded company and $4.1 million invested principally due to an increase in cash generated by during 1997 in the Rio Grande joint venture described earnings, offset partially by higher expenditures incurred below. The net negative cash flow for investing activities in fiscal 1998 relating to the Navajo turnaround was offset by distributions to the Company from the Rio compared to similar but smaller advance expenditures in Grande joint venture of $2.9 million in fiscal 1999 and the latter part of fiscal 1997 and offset by a $19.6 million $3.7 million in fiscal 1998. increase in inventories during 1997, primarily related to The Company has adopted a capital budget of $23 preparation for the turnaround in fiscal 1998. A million for fiscal 2000. The components of this budget significant portion of this inventory increase was are $9 million for various refinery improvements, $9 liquidated in fiscal 1998; however the impact of this million for costs relating to the purchase of a gasoil inventory liquidation was reduced because of an hydrotreater, as described below, $4 million for various increase in inventory caused by the Company’s purchase pipeline and transportation projects and under $1 million of the West Texas crude gathering system. for oil and gas exploration and production activities. In addition to these projects, the Company plans to expend Cash Flows for Financing Activities during 2000 a total of $8 million on items that were Cash flows used for financing activities amounted to approved in previous capital budgets primarily relating to $22.1 million in fiscal 1999, compared to $4.7 million in pipeline and terminalling activities. fiscal 1998 and $15.0 million in fiscal 1997. As part of its efforts to improve operating efficiencies, During 1999, increased cash flows from operating the Company constructed an isomerization unit and activities and lower capital expenditures relative to 1998 upgraded the FCC unit at the Navajo Refinery. The enabled the Company to retire its outstanding bank debt, isomerization unit, which was completed in February make scheduled amortization payments on the Senior 1997, increases the refinery’s internal octane generating Notes and pay $5.3 million in dividends. In 1998, higher capabilities, thereby improving light product yields and
  14. 14. HOLLY CORPORATION 12 increasing the refinery’s ability to upgrade additional venture (“Rio Grande”) with Mid-America Pipeline amounts of lower priced purchased natural gasoline into Company and Amoco Pipeline Company to transport finished gasoline. The upgrade of the refinery’s FCC unit, liquid petroleum gases to Mexico. Deliveries by the joint which was implemented during the Navajo Refinery’s venture began in April 1997. In October 1996, the scheduled turnaround in the first quarter and early part Company completed a new 12quot; refined products pipeline of the second quarter of fiscal 1998, improves the yield from Orla to El Paso, Texas, which replaced a portion of of high value products from the FCC unit by an 8quot; pipeline previously used by Navajo that was incorporating certain state-of-the-art upgrades. transferred to Rio Grande. Discussions regarding In addition to the above projects, the Company expansion of this line are currently underway. purchased a hydrotreater unit for $5 million from a The additional pipeline capacity resulting from the closed refinery in November 1997. This purchase should new pipelines constructed in conjunction with the Rio give the Company the ability to reconstruct the unit at Grande joint venture and from the Leased Pipeline the Navajo Refinery at a substantial savings relative to should reduce pipeline operating expenses at existing the purchase cost of a new unit. The hydrotreater will throughputs. In addition, the new pipeline capacity will enhance higher value, light product yields and facilitate allow the Company to increase volumes, through refinery the Company’s ability to meet the present California Air expansion or otherwise, that are shipped into existing Resources Board (“CARB”) standards, which have been and new markets and could allow the Company to shift adopted in the Company’s Phoenix market for winter volumes among markets in response to any future months beginning in the latter part of 2000. Included in increased competition in particular markets. the fiscal 2000 capital budget are commitments related In the fourth quarter of fiscal 1998, the Company to the hydrotreater of $9 million, which include costs to purchased from Fina Oil and Chemical Company a crude relocate the unit to the Navajo Refinery and construct a oil gathering system in West Texas. The assets purchased sulfur recovery unit, which will be immediately utilized include approximately 500 miles of pipelines and over and work in conjunction with the hydrotreater when 350,000 barrels of tankage. Approximately 23,000 completed, and certain long-lead-time pieces of barrels per day of crude oil were gathered on these equipment. The Company, subject to obtaining necessary systems in fiscal 1999. The Company believes that these permitting in a timely manner, expects to complete the assets should generate a stable source of transportation hydrotreater in the latter part of 2001. Remaining costs to service income, and will give Navajo the ability to complete the hydrotreater are estimated to be purchase crude oil at the lease in new areas, thus approximately $20 million, in addition to the current $9 potentially enhancing the stability of crude oil supply million budgeted amount. Based on the current and refined product margins for the Navajo Refinery. configuration at the Navajo Refinery, the Company During the fourth quarter of fiscal 1999, the Company believes it can supply current sales volumes into the completed 65 miles of new pipeline between Lovington Phoenix market under the CARB standards prior to and Artesia, New Mexico, to permit the delivery of completion of the hydrotreater. isobutane (and/or other LPGs) to an unrelated refiner in The Company has leased from Mid-America Pipeline El Paso as well as to increase the Company’s ability to Company more than 300 miles of 8quot; pipeline running access additional raw materials. from Chavez County to San Juan County, New Mexico The Company announced in February 1997 the (the “Leased Pipeline”). The Company has completed a formation of an alliance with FINA, Inc. (“FINA”) to 12quot; pipeline from the Navajo Refinery to the Leased create a comprehensive supply network that can increase Pipeline as well as terminalling facilities in Bloomfield. substantially the supplies of gasoline and diesel fuel in The Company is in the process of completing the the West Texas, New Mexico, and Arizona markets to construction of a diesel fuel terminal 40 miles east of meet expected increasing demand in the future. FINA Albuquerque in Moriarty and is considering different constructed a 50-mile pipeline which connected an alternatives regarding its terminalling needs in existing FINA pipeline system to the Company’s 12quot; Albuquerque. When the project, including the pipeline between Orla, Texas and El Paso, Texas pursuant Albuquerque portion, is completed, these facilities will to a long-term lease of certain capacity of the Company’s allow the Company to use the Leased Pipeline to 12quot; pipeline. In August 1998, FINA began transporting to transport petroleum products from the Navajo Refinery to El Paso gasoline and diesel fuel from its Big Spring, Texas Albuquerque and markets in northwest New Mexico. refinery. Pursuant to a long-term lease agreement, FINA Transportation of petroleum products to markets in will ultimately have the right to transport up to 20,000 northwest New Mexico and diesel fuels to Moriarty, New BPD to El Paso on this interconnected system. In August Mexico, near Albuquerque, are planned to begin in late 1998, the Company began to realize pipeline rental and 1999. terminalling revenues from FINA under these The Company has a 25% interest in a pipeline joint agreements.
  15. 15. HOLLY CORPORATION 13 ADDITIONAL FACTORS THAT MAY from the significant capital outlays associated with AFFECT FUTURE RESULTS refineries, terminals, pipelines and related facilities. Furthermore, future regulatory requirements or The Company’s operating results have been, and will competitive pressures could result in additional capital continue to be, affected by a wide variety of factors, expenditures, which may or may not produce the results many of which are beyond the Company’s control, that intended. Such capital expenditures may require could have adverse effects on profitability during any significant financial resources that may be contingent on particular period. Among these factors is the demand for the Company’s continued access to capital markets and crude oil and refined products, which is largely driven by commercial bank markets. Additionally, other matters, the conditions of local and worldwide economies as well such as regulatory requirements or legal actions may as by weather patterns and the taxation of these products restrict the Company’s continued access. relative to other energy sources. Governmental Until 1998, the El Paso market and markets served regulations and policies, particularly in the areas of from El Paso were generally not supplied by refined taxation, energy and the environment, also have a products produced by the large refineries on the Texas significant impact on the Company’s activities. Operating Gulf Coast. While wholesale prices of refined products results can be affected by these industry factors, by on the Gulf Coast have historically been lower than competition in the particular geographic markets that the prices in El Paso, distances from the Gulf Coast to El Paso Company serves and by factors that are specific to the (more than 700 miles if the most direct route is used) Company, such as the success of particular marketing have made transportation by truck unfeasible and have programs and the efficiency of the Company’s refinery discouraged the substantial investment required for operations. development of refined products pipelines from the Gulf In addition, the Company’s profitability depends Coast to El Paso. largely on the spread between market prices for refined In 1998, a Texaco, Inc. subsidiary completed a 16- petroleum products and crude oil prices. This margin is inch refined products pipeline running from the Gulf continually changing and may significantly fluctuate Coast to Midland, Texas along a northern route (through from time to time. Crude oil and refined products are Corsicana, Texas). This pipeline, now owned by Equilon commodities whose price levels are determined by Enterprises LLC (“Equilon”), is linked to a 6-inch market forces beyond the control of the Company. pipeline, also owned by Equilon, that is currently being Additionally, due to the seasonality of refined products used to transport to El Paso approximately 18,000 BPD of markets and refinery maintenance schedules, results of refined products that are produced on the Texas Gulf operations for any particular quarter of a fiscal year are Coast (this volume replaces a similar volume produced not necessarily indicative of results for the full year. In in the Shell Oil Company refinery in Odessa, Texas, general, prices for refined products are significantly which was recently shut down). The Equilon line from influenced by the price of crude oil. Although an the Gulf Coast to Midland has the potential to be linked increase or decrease in the price for crude oil generally to existing or new pipelines running from the Midland, results in a similar increase or decrease in prices for Texas area to El Paso with the result that substantial refined products, there is normally a time lag in the additional volumes of refined products could be realization of the similar increase or decrease in prices transported from the Gulf Coast to El Paso. for refined products. The effect of changes in crude oil An additional potential source of pipeline prices on operating results therefore depends in part on transportation from Gulf Coast refineries to El Paso is the how quickly refined product prices adjust to reflect these proposed Longhorn Pipeline. This pipeline is proposed to changes. A substantial or prolonged increase in crude oil run approximately 700 miles from the Houston area of prices without a corresponding increase in refined the Gulf Coast to El Paso, utilizing a direct route. The product prices, a substantial or prolonged decrease in owner of the Longhorn Pipeline, Longhorn Partners refined product prices without a corresponding decrease Pipeline, L.P., a Delaware limited partnership that in crude oil prices, or a substantial or prolonged includes affiliates of Exxon Pipeline Company, BP/Amoco decrease in demand for refined products could have a Pipeline Company, Williams Pipeline Company, and the significant negative effect on the Company’s earnings and Beacon Group Energy Investment Fund, L.P. and cash flows. Chisholm Holdings as limited partners (“Longhorn The Company is dependent on the production and Partners”), has proposed to use the pipeline initially to sale of quantities of refined products at margins sufficient transport approximately 72,000 BPD of refined products to cover operating costs, including any increases in costs from the Gulf Coast to El Paso and markets served from resulting from future inflationary pressures. The refining El Paso, with an ultimate maximum capacity of 225,000 business is characterized by high fixed costs resulting
  16. 16. HOLLY CORPORATION 14 BPD. A critical feature of this proposed petroleum operate as currently proposed. It is not possible to products pipeline is that it would utilize, for predict whether and, if so, under what conditions, the approximately 450 miles (including areas overlying the Longhorn Pipeline ultimately will be allowed to operate, environmentally sensitive Edwards Aquifer and Edwards- nor is it possible to predict the consequences for the Trinity Aquifer and heavily populated areas in the Company of Longhorn Pipeline’s operations if they occur. southern part of Austin, Texas) an existing pipeline In August 1998, a lawsuit (the “Longhorn Suit”) was (previously owned by Exxon Pipeline Company) that was filed by Longhorn Partners in state district court in El constructed in about 1950 for the shipment of crude oil Paso, Texas against the Company and two of its from West Texas to the Houston area. subsidiaries (along with an Austin, Texas law firm which The Longhorn Pipeline is not currently operating was subsequently dropped from the case). The suit, as because of a federal court injunction in August 1998 and amended by Longhorn Partners in March 1999, seeks a settlement agreement in March 1999 entered into by damages alleged to total up to $1,050,000,000 (after Longhorn Partners, the United States Environmental trebling) based on claims of violations of the Texas Free Protection Agency (“EPA”) and Department of Enterprise and Antitrust Act, unlawful interference with Transportation (“DOT”), and the other parties to the existing and prospective contractual relations, and federal lawsuit that had resulted in the injunction. The conspiracy to abuse process. The specific action of the March 1999 settlement agreement required the Company complained of in the Longhorn Suit is the preparation of an Environmental Assessment under the support of lawsuits brought by ranchers in West Texas to authority of the EPA and the DOT. A draft Environmental challenge the proposed use by the Longhorn Pipeline of Assessment (the “Draft EA”) on the Longhorn Pipeline easements and rights-of-way that were granted over 50 was released on October 22, 1999. The Draft EA years ago for the Exxon crude oil pipeline. The Company proposes a preliminary Finding of No Significant Impact believes that the Longhorn Suit is wholly without merit with respect to the Longhorn Pipeline provided that and plans to defend itself vigorously. The Company also Longhorn Partners carries out a proposed mitigation plan plans to pursue at the appropriate time any affirmative developed by Longhorn Partners which contains 34 remedies that may be available to it relating to the elements. Some of the elements of the proposed Longhorn Suit. mitigation plan are required to be completed before the In April 1999, the Williams Companies and Equilon Longhorn Pipeline is allowed to operate, with the Enterprises LLC (a joint venture of Texaco Inc. and the remainder required to be completed later or to be Royal Dutch/Shell Group) announced a 1,010-mile implemented for as long as operations continue. Public pipeline, called the “Aspen Pipeline,” to carry gasoline comments on the Draft EA may be submitted to the EPA and other refined fuels from Texas to Utah. It was and DOT until the end of November 1999 and in announced that the pipeline would have a capacity of November 1999 there will be a series of five public 65,000 BPD and shipments will begin in late 2000. In meetings on the Draft EA at specified locations in Texas. addition to the pipeline, product terminals would be The Company believes that public comments will raise built, including a terminal in Albuquerque, New Mexico. questions concerning certain elements of the Draft EA. A This venture could result in an increase in the supply of final determination by the EPA and DOT with respect to products to some of the Company’s markets. the matters considered in the Draft EA could be issued as An additional factor that could affect the Company’s early as 30 days following the end of the public market is excess pipeline capacity from the West Coast comment period. into the Company’s Arizona markets after the pipeline’s If the Longhorn Pipeline is allowed to operate as expansion this year. If additional refined products currently proposed, the substantially lower requirement become available on the West Coast in excess of for capital investment would permit Longhorn Partners to demand in that market, additional products may be give its shippers a cost advantage through lower tariffs shipped into the Company’s Arizona markets with that could, at least for a period, result in significant resulting possible downward pressure on refined product downward pressure on wholesale refined products prices prices in the Company’s markets. and refined products margins in El Paso and related In addition to the projects described above, other markets. Although some current suppliers in the market projects have been explored from time to time by refiners might not compete in such a climate, the Company’s and other entities, which projects, if consummated, analyses indicate that, because of location and recent could result in a further increase in the supply of capital improvements, the Company’s position in El Paso products to some or all of the Company’s markets. and markets served from El Paso could withstand such a In recent years there have been several refining and period of lower prices and margins. However, the marketing consolidations or acquisitions between entities Company’s results of operations could be adversely competing in the Company’s geographic market. While impacted if the Longhorn Pipeline were allowed to these transactions could increase the competitive
  17. 17. HOLLY CORPORATION 15 pressures on the Company, the specific ramifications of discussed above, will help the Company to meet these these or other potential consolidations cannot presently requirements. be determined. The common carrier pipelines used by the Company Risk Management to serve the Arizona and Albuquerque markets are The Company uses certain strategies to reduce some currently operated at or near capacity and are subject to commodity price and operational risks. The Company proration. As a result, the volumes of refined products does not attempt to eliminate all market risk exposures that the Company and other shippers have been able to when the Company believes the exposure relating to deliver to these markets have been limited. The flow of such risk would not be significant to the Company’s additional products into El Paso for shipment to Arizona, future earnings, financial position, capital resources or either as a result of the Longhorn Pipeline or otherwise, liquidity or that the cost of eliminating the exposure could further exacerbate such constraints on deliveries to would outweigh the benefit. Arizona. No assurances can be given that the Company The Company’s profitability depends largely on the will not experience future constraints on its ability to spread between market prices for refined products and deliver its products through the pipelines to Arizona. In crude oil. A substantial or prolonged decrease in this the case of the Albuquerque market, the common carrier spread could have a significant negative effect on the pipeline used by the Company to serve this market Company’s earnings, financial condition and cash flows. currently operates at or near capacity with resulting At times, the Company utilizes petroleum commodity limitations on the amount of refined products that the futures contracts to minimize a portion of its exposure to Company and other shippers can deliver. As previously price fluctuations associated with crude oil and refined discussed, the Company has entered into a Lease products. Such contracts are used solely to help manage Agreement for a pipeline between Artesia and the the price risk inherent in purchasing crude oil in advance Albuquerque vicinity and Bloomfield, New Mexico with of the delivery date and as a hedge for fixed-price sales Mid-America Pipeline Company. The Company has contracts of refined products and do not increase the completed a refined products terminal in Bloomfield and market risks to which the Company is exposed. Gains is completing construction of a diesel fuel terminal east and losses on contracts are deferred and recognized in of Albuquerque. The Company is also in the process of cost of refined products when the related inventory is pursuing different alternatives to address terminalling sold or the hedged transaction is consummated. No such needs in Albuquerque. While the Company is proceeding contracts were outstanding at July 31, 1999. as expeditiously as possible on the Albuquerque project, At July 31, 1999, the Company had outstanding it is not possible at present to determine when the unsecured debt of $70.3 million and had no borrowings project will be completed. Completion of this project outstanding under its Credit Agreement. The Company would allow the Company to transport products directly does not have significant exposure to changing interest to Albuquerque on the leased pipeline, thereby rates on its unsecured debt because the interest rates are eliminating third party tariff expenses and the risk of fixed, the average maturity is approximately three years future pipeline constraints on shipments to Albuquerque. and such debt represents less than 40% of the Any future constraints on the Company’s ability to Company’s total capitalization. During much of fiscal transport its refined products to Arizona or Albuquerque 1999, the Company had outstanding borrowings under could, if sustained, adversely affect the Company’s results the Credit Agreement. Since interest rates on borrowings of operations and financial condition. are reset frequently based on either the bank’s daily Effective January 1, 1995, certain cities in the country effective prime rate, or the LIBOR rate, interest rate were required to use only reformulated gasoline (“RFG”), market risk is very low. Additionally, the Company a cleaner burning fuel. Phoenix is the only principal invests any available cash only in investment grade, market of the Company that currently requires RFG highly liquid investments with maturities of three months although this requirement could be implemented in other or less. As a result, the interest rate market risk implicit in markets over time. Phoenix has adopted even more these cash investments is low, as the investments mature rigorous California Air Resources Board (“CARB”) fuel within three months. A ten percent change in the market specifications for winter months beginning in the latter interest rate over the next year would not materially part of 2000. This new requirement, other requirements impact the Company’s earnings or cash flow, as the of the federal Clean Air Act or other presently existing or interest rates on the Company’s long-term debt are fixed, future environmental regulations could cause the and the Company’s borrowings under the Credit Company to expend substantial amounts to permit the Agreement and cash investments are at short-term market Company’s refineries to produce products that meet rates and such interest has historically not been applicable requirements. Completion of the hydrotreater, significant as compared to the total operations of the
  18. 18. HOLLY CORPORATION 16 Company. A ten percent change in the market interest at risk of failure due to the Year 2000 Problem; the rate over the next year would not materially impact the Company believes that it has remediated all items of Company’s financial condition, as the average maturity of equipment containing at-risk chips. Because of the the Company’s long-term debt is approximately three nature of the non-IT systems, there can be no assurance years and such debt represents less than 40% of the that the Company has correctly identified all non-IT Company’s total capitalization, and the Company’s systems that are subject to failure because of the Year borrowings under the Credit Agreement and cash 2000 Problem. Any failure of non-IT systems because of investments are at short-term market rates. the Year 2000 Problem could reduce production levels or The Company’s operations are subject to normal potentially shut down the refinery operations of the hazards of operations, including fire, explosion and Company. weather-related perils. The Company maintains various To the extent possible, the Company has either tested insurance coverages, including business interruption or received certifications with respect to all significant IT insurance, subject to certain deductibles. The Company and non-IT systems. is not fully insured against certain risks because such The Company has also initiated contingency planning risks are not fully insurable, coverage is unavailable or to respond to the possible effects of the Year 2000 premium costs, in the judgement of the Company, do not Problem on third parties that are important to the justify such expenditures. Company’s operations. The Company is communicating regularly on this issue with critical third parties, such as The Year 2000 Problem suppliers of power or telecommunications services to the The Year 2000 Problem is the result of older computer Company’s operational facilities, third-party carriers of systems using a two-digit format rather than a four-digit raw materials and refined products, and major format to define the applicable year with the result that customers. As problems of third parties are identified such computer systems may be unable to interpret during the preparation of the contingency plan, the properly dates beyond the year 1999. This inability could Company will take any steps available to mitigate the lead to a failure of information systems and disruptions impact on the Company of a failure in a third party of business and financial operations. Year 2000 risks exist caused by the Year 2000 Problem. While the Company both in information technology (“IT”) systems that believes that it has made adequate arrangements to deal employ computer hardware and software and in non-IT with these contingencies, it continues to update such systems such as embedded computer chips or plans as additional information becomes available. microcontrollers that control the operation of the The cost to the Company of dealing with the Year equipment in which they are installed. Computer failures 2000 Problem is not expected to be material. Although a because of the Year 2000 Problem could affect the portion of the time of IT personnel and related Company either because of failures of computers used in management has been and will be employed in the Company’s operations and record-keeping or because evaluating the problem, taking corrective actions and of computer failures that adversely affect third parties preparing contingency plans, the Company does not that are suppliers to or customers of the Company. believe that other IT projects or operations have been or Partly with the assistance of outside consultants, the will be adversely affected. Monetary costs expected to be Company has taken steps to identify key financial, involved in dealing with the Year 2000 Problem are not informational and operational systems that may be expected to be significant: all costs to the Company of affected by the Year 2000 Problem. Based on review, analysis and corrective action (excluding IT certifications by third-party suppliers of the Company’s system upgrades that were scheduled to be implemented principal IT systems, the Company believes that its without regard to the Year 2000 Problem) are expected to principal IT systems either are now unaffected by the be slightly less than $1 million, most of which has been Year 2000 Problem or have been upgraded to make these incurred. systems free of Year 2000 issues. Based on the analysis performed to this point, the The Company has made an inventory of non-IT Company believes that the most important Year 2000 risk systems embedded in equipment used in the Company’s to the Company’s results of operations and financial operations and has assessed the extent to which these condition is that third-party suppliers important to the non-IT systems could fail because of the Year 2000 operations of the Company’s principal operating assets, Problem and thereby cause significant problems for the the Navajo Refinery at Artesia and Lovington, New Company’s operations, financial condition or liquidity. Mexico and the Montana Refinery near Great Falls, The Company has identified, based on information Montana, would for a period of time be unable to and/or certifications from suppliers or other third parties, perform their normal roles because of difficulties created the types of non-IT systems that appear to be significantly by the Year 2000 Problem for the third parties and/or for
  19. 19. HOLLY CORPORATION 17 persons supplying the third parties. The Company New Accounting Pronouncements believes that its most significant risk would be in the case In June 1998, the Financial Accounting Standards of the Company’s principal or sole sources for essential Board (“FASB”) issued Statement of Financial Accounting inputs — for example power to operate a refinery. If such Standards (“SFAS”) No. 133, “Accounting for Derivative a provider were to be unable to continue supplying the Instruments and Hedging Activities,” which requires that refinery because of the Year 2000 Problem, the Company all derivatives be recognized as either assets or liabilities could be forced to suspend the affected operations until in the statement of financial position and that those the provider could solve the problem or in some cases instruments be measured at fair value. SFAS No. 133 also until an alternative supply could be arranged. The prescribes the accounting treatment for changes in the Company intends to continue until the year 2000 regular fair value of derivatives which depends on the intended contacts with critical suppliers to determine their use of the derivative and the resulting designation. evaluations of vulnerability to the Year 2000 Problem. In Designations include hedges of the exposure to changes the event that a particular supplier appears to be in the fair value of a recognized asset or liability, hedges vulnerable, the Company will seek to obtain alternative of the exposure to variable cash flows of a forecasted supplies to the extent they are available. However, in the transaction, hedges of the exposure to foreign currency case of some inputs, alternative supplies may not translations, and derivatives not designated as hedging realistically be available even if the supply problem is instruments. In June 1999, the FASB issued SFAS No. identified months in advance. In other cases, an 137, “Accounting for Derivative Instruments and Hedging unexpected third-party failure could occur in spite of Activities - Deferral of the Effective Date of FASB extensive prior communications with key suppliers and Statement No. 133.” Under SFAS No. 137, SFAS No. 133 the only feasible remedy to the Company for a becomes effective for all fiscal quarters of all fiscal years substantial period might be emergency corrective action beginning after June 15, 2000 with early adoption by the affected third party if the third party were capable permitted. The Company has not completed evaluating of taking such action. the effects this statement will have on its financial reporting and disclosures. 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 at July 31, 1999 and 1998, and the related consolidated statements of income, cash flows, stockholders’ equity and comprehensive income for each of the three years in the period ended July 31, 1999. 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, 1999 and 1998, and the consolidated results of its operations and its cash flows for each of the three years in the period ended July 31, 1999, in conformity with generally accepted accounting principles. Dallas, Texas September 22, 1999

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