HOC Holly Corp.

DALLAS, Nov. 7 /PRNewswire-FirstCall/ -- Holly Corporation (NYSE:HOC) ("Holly") today reported record quarterly net income of $61.7 million ($2.02 per basic and $1.97 per diluted share) for the three months ended September 30, 2005, compared to net income of $11.5 million ($0.37 per basic and $0.36 per diluted share) for the three months ended September 30, 2004. Net income was $127.8 million ($4.09 per basic and $4.00 per diluted share) for the nine months ended September 30, 2005, compared to net income of $76.5 million ($2.43 per basic and $2.37 per diluted share) for the nine months ended September 30, 2004. Earnings for the third quarter of 2005 as compared to the third quarter of 2004 increased $50.2 million due principally to very high refined product margins experienced in the third quarter of 2005. Additionally favorably impacting earnings were increased production volumes offset by higher refinery operating costs and expenses. Company-wide refinery margins were $14.43 per produced barrel for the third quarter of 2005 compared to refinery margins of $7.41 per produced barrel for the third quarter of 2004. Earnings for the nine months ended September 30, 2005 increased 67.0% or $51.3 million from the nine months ended September 30, 2004. This increase was principally due to the very high refined product margins experienced in the third quarter of 2005 along with increased refinery production volumes offset by higher refinery costs and expenses. Company-wide refinery margins were $11.95 per produced barrel for the nine months ended September 30, 2005 compared to refinery margins of $9.82 per produced barrel for the first nine months of 2004. Additionally, in the nine months ended September 30, 2004, the Company received 100% of the benefit of the refined product pipelines and terminals contributed to Holly Energy Partners, L.P. (NYSE:HEP) ("HEP") prior to its initial public offering in July 2004, where subsequent to HEP's initial public offering in July 2004, including the current nine months ended September 30, 2005, approximately half of the income from HEP's refined product pipelines and terminals is attributable to owners other than the Company. Sales and other revenues increased 57% for the third quarter of 2005 and 45% for the first nine months of 2005 as compared to the third quarter and first nine months of 2004, respectively, due principally to higher product prices. Additionally, refined product sales volumes increased 4% in the third quarter as compared to the prior year's third quarter and increased 7% for the first nine months of 2005 as compared to the first nine months of 2004. Cost of products sold was higher in the third quarter and first nine months of 2005 due to the higher costs of purchased crude oil, and to a lesser degree, higher volumes. Additionally impacting sales and costs of sales were increases in the current year due to the inclusion of the NK Asphalt Partners joint venture (doing business as Holly Asphalt Company) in the 2005 consolidated financial statements, following the February 2005 purchase of the other partner's interest, and the inclusion of revenues from HEP's assets recently acquired from Alon through June 30, 2005 at which time HEP was deconsolidated. Operating expenses increased in the nine months ending September 30, 2005 as compared to the same period in the prior year, due principally to increased refinery utility costs and the inclusion of the NK Asphalt Partners joint venture in the 2005 consolidated financial statements, reduced by the operating costs of HEP in the 2005 third quarter which are no longer consolidated in the Company's results. "We are very pleased with our 2005 third quarter earnings, a record quarter, due to the extremely good margins, reliable refinery operations and the successful execution of our refinery profit improvement initiatives," said Matthew Clifton, President of Holly. "We generated $106.7 million of earnings before interest, taxes and depreciation ("EBITDA") in the quarter, bringing our year-to-date EBITDA to $238.9 million. Following the Gulf Coast hurricanes, margins spiked to unprecedented levels and continued at high levels into the fourth quarter. As more Gulf Coast refineries come back on line to full capacity, refined product prices should fall back, which we have started to see in recent weeks. As we have previously stated, we believe industry fundamentals remain in our favor for the foreseeable future as demand for refined products should continue to press refining supply capabilities, resulting in strong pricing for gasoline and distillate products. This situation is only magnified when there are supply disruptions, such as those experienced during and after the recent hurricanes." "Operationally, our refineries ran well during the quarter and we realized significant benefits from the execution of our previously announced value- added refinery initiatives for 2005, including strides to improve high value product yields, increase sour crude runs and raise refinery utilization rates at our facilities. Additionally, we are expecting to start up our new ROSE unit by the end of 2005, which will convert a significant portion of our lowest valued product into high valued transportation fuels. We are also well under way with our clean fuels projects at the Navajo and Woods Cross refineries, which should allow us to produce ultra low sulfur diesel fuel by 2006 deadline and will provide a phased-in 10,000 barrels-per-day expansion of the Navajo facility. The strong industry fundamentals combined with our high sour crude capabilities and our continued execution of value-added refining initiatives should keep our earnings at healthy levels. With respect to Holly Energy Partners, we are extremely pleased with its level of growth to date and look forward to its continued success. Additionally, we have now finished our $100 million stock repurchase program started in May 2005 and will continue in our commitment to build long-term value for our shareholders," said Clifton. The Company no longer consolidates the results of HEP, and since July 1, 2005, the share of the earnings of HEP is being recorded using the equity method of accounting. HEP has since July 2004 owned and operated product pipelines and terminals previously 100% owned by the Company. Following HEP's acquisition in July 2005 of the intermediate feedstock pipelines, the Company determined that its beneficial variable interest in HEP is now less than 50%; and therefore as required, HEP was deconsolidated as of July 1, 2005. Holly Corporation currently owns a 45% interest in HEP, including the general partner interest. Additionally, the Company has adopted Statement of Financial Accounting Standards ("SFAS") 123 (revised), "Share- Based Payment," which prescribes the accounting for a wide-range of share- based compensation arrangements. The Company elected early adoption of this standard on July 1, 2005 based on modified retrospective application with early application under SFAS 123 to prior quarters in the current year. Therefore the financial statements for periods ended March 31, 2005 and June 30, 2005 have been restated. This change resulted in increases in net income of $0.6 million in the three months ended March 31, 2005 and $0.4 million in the three months ended June 30, 2005. Additionally as part of the adoption of SFAS 123 (revised), a cumulative effect of a change in accounting principle was recorded of an increase in net income of $0.7 million in the three months ended September 30, 2005. The Company has scheduled a conference call for today, November 7, 2005 at 10:00AM EST to discuss financial results. Listeners may access this call by dialing (800) 858-5936. The ID# for this call is #1346989. Listeners may access the call via the internet at: http://audioevent.mshow.com/256727 . Additionally, listeners may replay this call approximately two hours after the call concludes by dialing (800) 642-1687. This audio archive will be available through November 21, 2005. Holly Corporation, headquartered in Dallas, Texas, is an independent petroleum refiner and marketer that produces high value light products such as gasoline, diesel fuel and jet fuel. Holly operates through its subsidiaries a 75,000 barrels per stream day ("bpsd") refinery located in Artesia, New Mexico, a 26,000 bpsd refinery in Woods Cross, Utah, and an 8,000 bpsd refinery in Great Falls, Montana. Holly also owns a 45% interest (including the general partner interest) in Holly Energy Partners, L.P., which through subsidiaries owns or leases approximately 1,600 miles of petroleum product pipelines in Texas, New Mexico and Oklahoma and refined product terminals in several Southwest and Rocky Mountain states. The following is a "safe harbor" statement under the Private Securities Litigation Reform Act of 1995: The statements in this press release relating to matters that are not historical facts are "forward-looking statements" based on management's belief and assumptions using currently available information and expectations as of the date hereof, are not guarantees of future performance and involve certain risks and uncertainties, including those contained in our filings with the Securities and Exchange Commission. Although we believe that the expectations reflected in these forward-looking statements are reasonable, we cannot assure you that our expectations will prove correct. Therefore, actual outcomes and results could materially differ from what is expressed, implied or forecast in such statements. Such differences could be caused by a number of factors including, but not limited to, risks and uncertainties with respect to the actions of actual or potential competitive suppliers of refined petroleum products in the Company's markets, the demand for and supply of crude oil and refined products, the spread between market prices for refined products and market prices for crude oil, the possibility of constraints on the transportation of refined products, the possibility of inefficiencies or shutdowns in refinery operations or pipelines, effects of governmental regulations and policies, the availability and cost of financing to the Company, the effectiveness of the Company's capital investments and marketing strategies, the ability of the Company or Holly Energy Partners, L. P. to acquire refined product operations or pipeline and terminal operations on acceptable terms and to integrate any future acquired operations, the Company's efficiency in carrying out construction projects, the possibility of terrorist attacks and the consequences of any such attacks, general economic conditions, and other financial, operational and legal risks and uncertainties detailed from time to time in the Company's Securities and Exchange Commission filings. The forward-looking statements speak only as of the date made and, other than as required by law, we undertake no obligation to publicly update or revise any forward-looking statements, whether as a result of new information, future events or otherwise. RESULTS OF OPERATIONS Financial Data (all information in this release is unaudited) Three Months Ended Nine Months Ended September 30, September 30, 2005 2004 2005 2004 (In thousands, except per share data) Sales and other revenues $935,279 $597,448 $2,358,300 $1,629,240 Operating costs and expenses: Cost of products sold (exclusive of depreciation, depletion, and amortization) 772,887 507,630 1,933,915 1,308,179 Operating expenses (exclusive of depreciation, depletion, and amortization) 46,947 46,762 146,187 127,494 General and administrative expenses (exclusive of depreciation, depletion and amortization) 12,616 12,001 35,527 35,947 Depreciation, depletion and amortization 9,390 9,985 34,336 29,840 Exploration expenses, including dry holes 69 122 310 550 Total operating costs and expenses 841,909 576,500 2,150,275 1,502,010 Income from operations 93,370 20,948 208,025 127,230 Other income (expense): Equity in earnings (loss) of joint ventures --- 348 (685) 293 Equity in earnings of Holly Energy Partners 3,296 --- 3,296 --- Minority interests in income of partnerships --- (2,704) (6,721) (3,699) Interest income 1,202 933 4,455 3,323 Interest expense (501) (922) (4,706) (2,628) 3,997 (2,345) (4,361) (2,711) Income before income taxes 97,367 18,603 203,664 124,519 Income tax provision 36,317 7,078 76,556 48,025 Income before cumulative change in accounting principle 61,050 11,525 127,108 76,494 Cumulative effect of accounting change (net of income tax expense of $426) 669 --- 669 --- Net income $61,719 $11,525 $127,777 $76,494 Basic earnings per share: Income before cumulative change in accounting principle $2.00 $0.37 $4.07 $2.43 Cumulative effect of accounting change 0.02 --- 0.02 --- Net income $2.02 $0.37 $4.09 $2.43 Diluted earnings per share: Income before cumulative change in accounting principle $1.95 $0.36 $3.98 $2.37 Cumulative effect of accounting change 0.02 --- 0.02 --- Net income $1.97 $0.36 $4.00 $2.37 Cash dividends declared per common share $0.10 $0.08 $0.28 $0.21 Average number of common shares outstanding: Basic 30,618 31,513 31,253 31,444 Diluted 31,386 32,420 31,980 32,316 Balance Sheet Data September 30, December 31, 2005 (B) 2004 (In thousands) Cash, cash equivalents and investments in marketable securities $273,651 $219,265 Working capital $255,280 $148,642 Total assets $1,197,257 $982,713 Total debt, including current maturities and bank borrowings (A) $8,572 $33,572 Minority interests $--- $157,550 Stockholders' equity $389,021 $339,916 (A) Includes HEP's bank borrowings of $25.0 million at December 31, 2004. (B) There are no HEP balances included at September 30, 2005 due to the deconsolidation on July 1, 2005. Other Financial Data Three Months Ended Nine Months Ended September 30, September 30, 2005 2004 2005 2004 (In thousands) Net cash provided by operating activities $86,079 $37,081 $158,559 $160,381 Net cash provided by (used for) investing activities $(136,789) $46,980 $(287,212) $30,737 Net cash provided by (used for) financing activities $15,418 $9,042 $137,502 $(45,307) Capital expenditures $29,417 $8,796 $58,062 $27,915 EBITDA (A) $106,725 $28,577 $238,920 $153,664 (A) Earnings before interest, taxes, depreciation and amortization, which we refer to as EBITDA as presented above is reconciled to net income under "Reconciliations to Amounts Reported under Generally Accepted Accounting Principles" below. Our major business segment is Refining after the deconsolidation of HEP on July 1, 2005 and Refining and HEP prior to the deconsolidation. The Refining segment presented in the September 30, 2004 quarterly report on Form 10-Q is not the same Refining segment as presented below. The Refining segment for the three months and nine months ended September 30, 2004 has been reported to include results of operations involving assets included in HEP prior to the contribution on July 13, 2004. The HEP segment did not have any activity prior to HEP's formation on July 13, 2004 or subsequent to the deconsolidation effective on July 1, 2005. Three Months Ended Nine Months Ended September 30, September 30, 2005 2004 2005 2004 (In thousands) Sales and other revenues (A) Refining $934,987 $593,010 $2,340,931 $1,623,936 HEP --- 12,190 36,034 12,190 Corporate and Other 417 399 1,034 1,496 Consolidations and Eliminations (125) (8,151) (19,699) (8,382) Consolidated $935,279 $597,448 $2,358,300 $1,629,240 Income (loss) from operations (A) Refining $105,922 $25,421 $225,708 $152,231 HEP --- 5,432 16,019 5,432 Corporate and Other (12,552) (9,905) (33,702) (30,433) Consolidated $93,370 $20,948 $208,025 $127,230 (A) The Refining segment involves the purchase and refining of crude oil and wholesale and branded marketing of refined products, such as gasoline, diesel fuel and jet fuel, and includes our Navajo Refinery, Montana Refinery and Woods Cross Refinery. The petroleum products produced by the Refining segment are marketed in Texas, New Mexico, Arizona, Utah, Wyoming, Montana, Idaho, Washington and northern Mexico. The Refining segment also includes certain crude oil and intermediate product pipelines, prior to July 8, 2005 (see Note 2 to our consolidated financial statements), that we owned and operated in conjunction with our refining operations as part of the supply networks of the refineries. In February 2005, we acquired the remaining 51% interest in our asphalt joint venture from the other partner; subsequent to the purchase, we are including the operations of NK Asphalt Partners in our consolidated financial statements. NK Asphalt Partners, dba Holly Asphalt Company, manufactures and markets asphalt and asphalt products in Arizona, New Mexico, Texas and California. The cost of pipeline transportation and terminal services provided by HEP is also included in the Refining segment. The HEP segment involved all of the operations of HEP through June 30, 2005 (prior to the deconsolidation), including approximately 1,300 miles (780 miles prior to the Alon asset acquisition) of its pipeline assets principally in Texas, New Mexico and Oklahoma and refined product terminals in several Southwest and Rocky Mountain States. The HEP segment also included its 70% interest in Rio Grande, which provides petroleum products transportation. Revenues from the HEP segment were earned through transactions with unaffiliated parties for pipeline transportation, rental and terminalling operations as well as revenues relating to pipeline transportation services provided for our refining operations and from HEP's interest in Rio Grande. Results of operations involving the assets included in the HEP segment prior to July 13, 2004 are included in the Refining segment for reporting purposes. Our operations not included in the two reportable segments are included in Corporate and Other, which includes costs of Holly Corporation, the parent company, consisting primarily of general and administrative expenses as well as a small- scale oil and gas exploration and production program. The consolidations and eliminations amount includes the elimination of the revenue associated with our pipeline transportation services between us and HEP for the six months ended June 30, 2005. Refining Operating Data Our refinery operations include the Navajo Refinery, the Woods Cross Refinery and the Montana Refinery. The following tables set forth information, including non-generally accepted accounting principles ("GAAP") performance measures about our refinery operations. The cost of products and refinery gross margin do not include the effect of depreciation, depletion and amortization. Reconciliations to amounts reported under GAAP are presented under "Reconciliations to Amounts Reported under Generally Accepted Accounting Principles." Three Months Ended Nine Months Ended September 30, September 30, 2005 2004 2005 2004 Navajo Refinery Crude charge (BPD) (A) 73,030 69,470 73,080 70,160 Refinery production (BPD) (B) 79,660 76,250 80,470 77,910 Sales of produced refined products (BPD) 80,280 76,810 80,160 77,410 Sales of refined products (BPD) (C) 87,830 86,660 89,130 85,050 Refinery utilization (D) 97.4% 92.6% 97.4% 93.5% Average per produced barrel (E) Net sales $79.18 $52.71 $67.46 $50.12 Cost of products (F) 63.38 44.15 54.21 39.00 Refinery gross margin (G) 15.80 8.56 13.25 11.12 Refinery operating expenses 3.65 3.47 3.48 3.24 Net operating margin $12.15 $5.09 $9.77 $7.88 Feedstocks: Sour crude oil 87% 86% 88% 82% Sweet crude oil 2% 3% 1% 6% Other feedstocks and blends 11% 11% 11% 12% Total 100% 100% 100% 100% Sales of produced refined products: Gasolines 57% 57% 58% 58% Diesel fuels 29% 27% 28% 26% Jet fuels 4% 5% 4% 6% Asphalt 5% 8% 6% 7% LPG and other 5% 3% 4% 3% Total 100% 100% 100% 100% Three Months Ended Nine Months Ended September 30, September 30, 2005 2004 2005 2004 Woods Cross Refinery Crude charge (BPD) (A) 24,350 25,560 23,970 23,750 Refinery production (BPD) (B) 26,190 25,560 25,760 23,930 Sales of produced refined products (BPD) 27,240 24,600 26,710 23,720 Sales of refined products (BPD) (C) 28,840 25,800 27,960 24,330 Refinery utilization (D) 93.7% 102.2% 92.2% 95.0% Average per produced barrel (E) Net sales $81.72 $53.06 $68.23 $50.34 Cost of products (F) 68.65 48.80 59.26 44.00 Refinery gross margin (G) 13.07 4.26 8.97 6.34 Refinery operating expenses 4.11 3.93 4.18 3.93 Net operating margin $8.96 $0.33 $4.79 $2.41 Feedstocks: Sour crude oil 7% 7% 8% 6% Sweet crude oil 81% 88% 81% 88% Other feedstocks and blends 12% 5% 11% 6% Total 100% 100% 100% 100% Sales of produced refined products: Gasolines 63% 58% 61% 59% Diesel fuels 30% 33% 29% 32% Jet fuels 2% 2% 2% 1% Fuel oil 4% 6% 6% 7% LPG and other 1% 1% 2% 1% Total 100% 100% 100% 100% Montana Refinery Crude charge (BPD) (A) 8,240 8,310 7,900 7,460 Refinery production (BPD) (B) 8,790 8,910 8,380 7,920 Sales of produced refined products (BPD) 10,980 10,010 8,510 7,960 Sales of refined products (BPD) (C) 11,280 10,210 8,700 8,180 Refinery utilization (D) 103.0% 103.9% 98.8% 93.3% Average per produced barrel (E) Net sales $52.47 $43.79 $52.70 $42.89 Cost of products (F) 44.66 37.60 43.58 35.36 Refinery gross margin 7.81 6.19 9.12 7.53 Refinery operating expenses 4.61 4.83 6.10 5.61 Net operating margin $3.20 $1.36 $3.02 $1.92 Feedstocks: Sour crude oil 92% 91% 93% 92% Other feedstocks and blends 8% 9% 7% 8% Total 100% 100% 100% 100% Three Months Ended Nine Months Ended September 30, September 30, 2005 2004 2005 2004 Montana Refinery Sales of produced refined products: Gasolines 29% 35% 38% 41% Diesel fuels 13% 15% 17% 17% Jet fuels 5% 6% 5% 6% Asphalt 50% 41% 36% 32% LPG and other 3% 3% 4% 4% Total 100% 100% 100% 100% Consolidated Crude charge (BPD) (A) 105,620 103,340 104,950 101,370 Refinery production (BPD) (B) 114,640 110,720 114,610 109,760 Sales of produced refined products (BPD) 118,500 111,420 115,380 109,090 Sales of refined products (BPD) (C) 127,950 122,670 125,790 117,560 Refinery utilization (D) 96.9% 95.7% 96.3% 93.9% Average per produced barrel (E) Net sales $77.29 $51.99 $66.55 $49.64 Cost of products (F) 62.86 44.58 54.60 39.82 Refinery gross margin (G) 14.43 7.41 11.95 9.82 Refinery operating expenses 3.85 3.70 3.84 3.56 Net operating margin $10.58 $3.71 $8.11 $6.26 Feedstocks: Sour crude oil 69% 68% 70% 66% Sweet crude oil 20% 23% 19% 24% Other feedstocks and blends 11% 9% 11% 10% Total 100% 100% 100% 100% Sales of produced refined products: Gasolines 56% 56% 58% 57% Diesel fuels 27% 27% 27% 27% Jet fuels 4% 4% 4% 5% Asphalt 8% 9% 7% 7% LPG and other 5% 4% 4% 4% Total 100% 100% 100% 100% (A) Crude charge represents the barrels per day of crude oil processed at the crude units at our refineries. (B) Refinery production represents the barrels per day of refined products yielded from processing crude and other refinery feedstocks through the crude units and other conversion units at our refineries. (C) Includes refined products purchased for resale. (D) Represents crude charge divided by total crude capacity. (E) Represents average per barrel amounts for produced refined products sold, which are non-GAAP. Reconciliations to amounts reported under GAAP are located under "Reconciliations to Amounts Reported under Generally Accepted Accounting Principles." (F) Subsequent to the formation of HEP, transportation costs billed from HEP are included in cost of products. (G) Represents operating expenses of our refinery, exclusive of depreciation, depletion, and amortization, and excludes refining segment expenses of product pipelines and terminals. Reconciliations to Amounts Reported Under Generally Accepted Accounting Principles Reconciliations of earnings before interest, taxes, depreciation and amortization ("EBITDA") to amounts reported under generally accepted accounting principles in financial statements. Earnings before interest, taxes, depreciation and amortization, which we refer to as EBITDA, is calculated as net income plus (i) interest expense net of interest income, (ii) income tax provision, and (iii) depreciation, depletion and amortization. EBITDA is not a calculation based upon accounting principles generally accepted in the United States; however, the amounts included in the EBITDA calculation are derived from amounts included in our consolidated financial statements. EBITDA should not be considered as an alternative to net income or operating income as an indication of our operating performance or as an alternative to operating cash flow as a measure of liquidity. EBITDA is not necessarily comparable to similarly titled measures of other companies. EBITDA is presented here because it is a widely used financial indicator used by investors and analysts to measure performance. EBITDA is also used by our management for internal analysis and as a basis for financial covenants. Set forth below is our calculation of EBITDA. Three Months Ended Nine Months Ended September 30, September 30, 2005 2004 2005 2004 (In thousands) Net income $61,719 $11,525 $127,777 $76,494 Add provision for income tax 36,317 7,078 76,556 48,025 Add interest expense 501 922 4,706 2,628 Subtract interest income (1,202) (933) (4,455) (3,323) Add depreciation, depletion and amortization 9,390 9,985 34,336 29,840 EBITDA $106,725 $28,577 $238,920 $153,664 Reconciliations of refinery operating information (non-GAAP performance measures) to amounts reported under generally accepted accounting principles in financial statements. Refinery gross margin and net operating margin are non-GAAP performance measures that are used by our management and others to compare our refining performance to that of other companies in our industry. We believe these margin measures are helpful to investors in evaluating our refining performance on a relative and absolute basis. We calculate refinery gross margin and net operating margin using net sales, cost of products and operating expenses, in each case averaged per produced barrel sold. These two margins do not include the effect of depreciation, depletion and amortization. Each of these component performance measures can be reconciled directly to our Consolidated Statement of Income. Other companies in our industry may not calculate these performance measures in the same manner. Refinery Gross Margin Refinery gross margin per barrel is the difference between average net sales price and average cost of products per barrel of produced refined products. Refinery gross margin for each of our refineries and for all of our refineries on a consolidated basis is calculated as shown below. Three Months Ended Nine Months Ended September 30, September 30, 2005 2004 2005 2004 Average per produced barrel Navajo Refinery Net sales $79.18 $52.71 $67.46 $50.12 Less cost of products 63.38 44.15 54.21 39.00 Refinery gross margin $15.80 $8.56 $13.25 $11.12 Woods Cross Refinery Net sales $81.72 $53.06 $68.23 $50.34 Less cost of products 68.65 48.80 59.26 44.00 Refinery gross margin $13.07 $4.26 $8.97 $6.34 Montana Refinery Net sales $52.47 $43.79 $52.70 $42.89 Less cost of products 44.66 37.60 43.58 35.36 Refinery gross margin $7.81 $6.19 $9.12 $7.53 Consolidated Net sales $77.29 $51.99 $66.55 $49.64 Less cost of products 62.86 44.58 54.60 39.82 Refinery gross margin $14.43 $7.41 $11.95 $9.82 Net Operating Margin Net operating margin per barrel is the difference between refinery gross margin and refinery operating expenses per barrel of produced refined products. Net operating margin for each of our refineries and for all of our refineries on a consolidated basis is calculated as shown below. Three Months Ended Nine Months Ended September 30, September 30, 2005 2004 2005 2004 Average per produced barrel Navajo Refinery Refinery gross margin $15.80 $8.56 $13.25 $11.12 Less refinery operating expenses 3.65 3.47 3.48 3.24 Net operating margin $12.15 $5.09 $9.77 $7.88 Woods Cross Refinery Refinery gross margin $13.07 $4.26 $8.97 $6.34 Less refinery operating expenses 4.11 3.93 4.18 3.93 Net operating margin $8.96 $0.33 $4.79 $2.41 Three Months Ended Nine Months Ended September 30, September 30, 2005 2004 2005 2004 Average per produced barrel Montana Refinery Refinery gross margin $7.81 $6.19 $9.12 $7.53 Less refinery operating expenses 4.61 4.83 6.10 5.61 Net operating margin $3.20 $1.36 $3.02 $1.92 Consolidated Refinery gross margin $14.43 $7.41 $11.95 $9.82 Less refinery operating expenses 3.85 3.70 3.84 3.56 Net operating margin $10.58 $3.71 $8.11 $6.26 Below are reconciliations to our Consolidated Statement of Income for (i) net sales, cost of products and operating expenses, in each case averaged per produced barrel sold, and (ii) net operating margin and refinery gross margin. Due to rounding of reported numbers, some amounts may not calculate exactly. Reconciliations of refined product sales from produced products sold to total sales and other revenue Three Months Ended Nine Months Ended September 30, September 30, 2005 2004 2005 2004 Navajo Refinery Average sales price per produced barrel sold $79.18 $52.71 $67.46 $50.12 Times sales of produced refined products sold (BPD) 80,280 76,810 80,160 77,410 Times number of days in period 92 92 273 274 Refined product sales from produced products sold $584,804 $372,476 $1,476,273 $1,063,062 Woods Cross Refinery Average sales price per produced barrel sold $81.72 $53.06 $68.23 $50.34 Times sales of produced refined products sold (BPD) 27,240 24,600 26,710 23,720 Times number of days in period 92 92 273 274 Refined product sales from produced products sold $204,797 $120,085 $497,522 $327,174 Montana Refinery Average sales price per produced barrel sold $52.47 $43.79 $52.70 $42.89 Times sales of produced refined products sold (BPD) 10,980 10,010 8,510 7,960 Times number of days in period 92 92 273 274 Refined product sales from produced products sold $53,003 $40,327 $122,434 $93,545 Sum of refined products sales from produced products sold from our three refineries (C) $842,604 $532,888 $2,096,229 $1,483,781 Add refined product sales from purchased products and rounding (A) 69,739 58,293 196,185 126,032 Total refined products sales 912,343 591,181 2,292,414 1,609,813 Add other refining segment revenue (B) 22,644 1,829 48,517 14,123 Total refining segment revenue 934,987 593,010 2,340,931 1,623,936 Add HEP sales and other revenue --- 12,190 36,034 12,190 Add corporate and other revenues 417 399 1,034 1,496 Subtract consolidations and eliminations (125) (8,151) (19,699) (8,382) Sales and other revenues $935,279 $597,448 $2,358,300 $1,629,240 (A) We purchase finished products when opportunities arise that provide a profit on the sale of such products, or to meet delivery commitments. (B) Other refining segment revenue includes the revenues associated with NK Asphalt Partners subsequent to their consolidation in February 2005 and revenues during 2004 from terminal and pipeline assets that are now owned by HEP. (C) The above calculations of refined product sales from produced products sold can also be computed on a consolidated basis. These amounts may not calculate exactly due to rounding of reported numbers. Three Months Ended Nine Months Ended September 30, September 30, 2005 2004 2005 2004 Average sales price per produced barrel sold $77.29 $51.99 $66.55 $49.64 Times sales of produced refined products sold (BPD) 118,500 111,420 115,380 109,090 Times number of days in period 92 92 273 274 Refined product sales from produced products sold $842,604 $532,888 $2,096,229 $1,483,781 Reconciliation of average cost of products per produced barrel sold to total costs of products sold Three Months Ended Nine Months Ended September 30, September 30, 2005 2004 2005 2004 Navajo Refinery Average cost of products per produced barrel sold $63.38 $44.15 $54.21 $39.00 Times sales of produced refined products sold (BPD) 80,280 76,810 80,160 77,410 Times number of days in period 92 92 273 274 Cost of products for produced products sold $468,109 $311,987 $1,186,314 $827,203 Woods Cross Refinery Average cost of products per produced barrel sold $68.65 $48.80 $59.26 $44.00 Times sales of produced refined products sold (BPD) 27,240 24,600 26,710 23,720 Times number of days in period 92 92 273 274 Cost of products for produced products sold $172,042 $110,444 $432,114 $285,968 Montana Refinery Average cost of products per produced barrel sold $44.66 $37.60 $43.58 $35.36 Times sales of produced refined products sold (BPD) 10,980 10,010 8,510 7,960 Times number of days in period 92 92 273 274 Cost of products for produced products sold $45,114 $34,627 $101,246 $77,122 Sum of cost of products for produced products sold from our three refineries (C) $685,265 $457,058 $1,719,674 $1,190,293 Add refined product costs from purchased products sold and rounding (A) 71,039 58,723 200,061 126,268 Total refined costs of products sold 756,304 515,781 1,919,735 1,316,561 Add other refining segment costs of products sold (B) 16,708 --- 33,879 --- Total refining segment cost of products sold 773,012 515,781 1,953,614 1,316,561 Subtract consolidations and eliminations (125) (8,151) (19,699) (8,382) Costs of products sold (exclusive of depreciation, depletion and amortization) $772,887 $507,630 $1,933,915 $1,308,179 (A) We purchase finished products when opportunities arise that provide a profit on the sale of such products, or to meet delivery commitments. (B) Other refining segment costs of products sold includes the cost of products for NK Asphalt Partners subsequent to their consolidation in February 2005. (C) The above calculations of refined product sales from produced products sold can also be computed on a consolidated basis. These amounts may not calculate exactly due to rounding of reported numbers. Three Months Ended Nine Months Ended September 30, September 30, 2005 2004 2005 2004 Average cost of products per produced barrel sold $62.86 $44.58 $54.60 $39.82 Times sales of produced refined products sold (BPD) 118,500 111,420 115,380 109,090 Times number of days in period 92 92 273 274 Cost of products for produced products sold $685,265 $457,058 $1,719,674 $1,190,293 Reconciliation of average refinery operating expenses per produced barrel sold to total operating expenses Three Months Ended Nine Months Ended September 30, September 30, 2005 2004 2005 2004 Navajo Refinery Average refinery operating expenses per produced barrel sold $3.65 $3.47 $3.48 $3.24 Times sales of produced refined products sold (BPD) 80,280 76,810 80,160 77,410 Times number of days in period 92 92 273 274 Refinery operating expenses for produced products sold $26,958 $24,521 $76,155 $68,722 Woods Cross Refinery Average refinery operating expenses per produced barrel sold $4.11 $3.93 $4.18 $3.93 Times sales of produced refined products sold (BPD) 27,240 24,600 26,710 23,720 Times number of days in period 92 92 273 274 Refinery operating expenses for produced products sold $10,300 $8,894 $30,480 $25,542 Montana Refinery Average refinery operating expenses per produced barrel sold $4.61 $4.83 $6.10 $5.61 Times sales of produced refined products sold (BPD) 10,980 10,010 8,510 7,960 Times number of days in period 92 92 273 274 Refinery operating expenses for produced products sold $4,657 $4,448 $14,172 $12,236 Sum of refinery operating expenses per produced products sold from our three refineries (B) $41,915 $37,863 $120,807 $106,500 Add other refining segment operating expenses and rounding (A) 5,032 4,509 13,544 16,471 Total refining segment operating expenses 46,947 42,372 134,351 122,971 Add HEP operating expenses --- 4,368 11,836 4,368 Add corporate and other costs --- 22 --- 155 Operating expenses (exclusive of depreciation, depletion and amortization) $46,947 $46,762 $146,187 $127,494 (A) Other refining segment operating expenses includes the marketing costs associated with our refining segment, the operating expenses of NK Asphalt Partners subsequent to their consolidation in February 2005 and the operating expenses during 2004 of terminal and pipeline assets now owned by HEP. (B) The above calculations of refined product sales from produced products sold can also be computed on a consolidated basis. These amounts may not calculate exactly due to rounding of reported numbers. Three Months Ended Nine Months Ended September 30, September 30, 2005 2004 2005 2004 Average refinery operating expenses per produced barrel sold $3.85 $3.70 $3.84 $3.56 Times sales of produced refined products sold (BPD) 118,500 111,420 115,380 109,090 Times number of days in period 92 92 273 274 Refinery operating expenses for produced products sold $41,915 $37,863 $120,807 $106,500 Reconciliation of net operating margin per barrel to refinery gross margin per barrel to total sales and other revenues Three Months Ended Nine Months Ended September 30, September 30, 2005 2004 2005 2004 Navajo Refinery Net operating margin per produced barrel $12.15 $5.09 $9.77 $7.88 Add average refinery operating expenses per produced barrel 3.65 3.47 3.48 3.24 Refinery gross margin per produced barrel 15.80 8.56 13.25 11.12 Add average cost of products per produced barrel sold 63.38 44.15 54.21 39.00 Average net sales per produced barrel sold $79.18 $52.71 $67.46 $50.12 Times sales of produced refined products sold (BPD) 80,280 76,810 80,160 77,410 Times number of days in period 92 92 273 274 Refined product sales from produced products sold $584,804 $372,476 $1,476,273 $1,063,062 Woods Cross Refinery Net operating margin per produced barrel $8.96 $0.33 $4.79 $2.41 Add average refinery operating expenses per produced barrel 4.11 3.93 4.18 3.93 Refinery gross margin per produced barrel 13.07 4.26 8.97 6.34 Add average cost of products per produced barrel sold 68.65 48.80 59.26 44.00 Average net sales per produced barrel sold $81.72 $53.06 $68.23 $50.34 Times sales of produced refined products sold (BPD) 27,240 24,600 26,710 23,720 Times number of days in period 92 92 273 274 Refined product sales from produced products sold $204,797 $120,085 $497,522 $327,174 Montana Refinery Net operating margin per produced barrel $3.20 $1.36 $3.02 $1.92 Add average refinery operating expenses per produced barrel 4.61 4.83 6.10 5.61 Refinery gross margin per produced barrel 7.81 6.19 9.12 7.53 Add average cost of products per produced barrel sold 44.66 37.60 43.58 35.36 Average net sales per produced barrel sold $52.47 $43.79 $52.70 $42.89 Times sales of produced refined products sold (BPD) 10,980 10,010 8,510 7,960 Times number of days in period 92 92 273 274 Refined product sales from produced products sold $53,003 $40,327 $122,434 $93,545 Three Months Ended Nine Months Ended September 30, September 30, 2005 2004 2005 2004 Sum of refined product sales from produced products sold from our three refineries (C) $842,604 $532,888 $2,096,229 $1,483,781 Add refined product sales from purchased products and rounding (A) 69,739 58,293 196,185 126,032 Total refining product sales 912,343 591,181 2,292,414 1,609,813 Add other refining segment revenue (B) 22,644 1,829 48,517 14,123 Total refining segment revenue 934,987 593,010 2,340,931 1,623,936 Add HEP sales and other revenue --- 12,190 36,034 12,190 Add corporate and other revenues 417 399 1,034 1,496 Subtract consolidations and eliminations (125) (8,151) (19,699) (8,382) Sales and other revenues $935,279 $597,448 $2,358,300 $1,629,240 (A) We purchase finished products when opportunities arise that provide a profit on the sale of such products, or to meet delivery commitments. (B) Other refining segment revenue includes the revenues associated with NK Asphalt Partners subsequent to their consolidation in February 2005 and revenues during 2004 from terminal and pipeline assets that are now owned by HEP. (C) The above calculations of refined product sales from produced products sold can also be computed on a consolidated basis. These amounts may not calculate exactly due to rounding of reported numbers. Three Months Ended Nine Months Ended September 30, September 30, 2005 2004 2005 2004 Net operating margin per produced barrel $10.58 $3.71 $8.11 $6.26 Average refinery operating expenses per produced barrel 3.85 3.70 3.84 3.56 Refinery gross margin per produced barrel 14.43 7.41 11.95 9.82 Add average cost of products per produced barrel sold 62.86 44.58 54.60 39.82 Average net sales per produced barrel sold $77.29 $51.99 $66.55 $49.64 Times sales of produced refined products sold (BPD) 118,500 111,420 115,380 109,090 Times number of days in period 92 92 273 274 Refined product sales from produced products sold $842,604 $532,888 $2,096,229 $1,483,781 DATASOURCE: Holly Corporation CONTACT: Stephen J. McDonnell, Vice President and Chief Financial Officer, or M. Neale Hickerson, Vice President, Investor Relations, both of Holly Corporation, +1-214-871-3555 Web site: http://www.hollycorp.com/ http://audioevent.mshow.com/256727

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