UNITED STATES SECURITIES AND EXCHANGE COMMISSION
WASHINGTON, D.C. 20549
FORM 10-Q/A
| [X] | Quarterly Report pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934 FOR THE QUARTERLY PERIOD ENDED MARCH 31, 2003 OR |
| [ ] | Transition Report pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934 For the transition period from . . . . to . . . . Commission file number 1-7627 |
FRONTIER OIL CORPORATION
(Exact name of registrant as specified in its charter)
| Wyoming (State or other jurisdiction of incorporation or organization) 10000 Memorial Drive, Suite 600 Houston, Texas (Address of principal executive offices) | 74-1895085 (I.R.S. Employer Identification No.) 77024-3411 (Zip Code) |
Registrant’s telephone number, including area code:(713) 688-9600
Former name, former address and former fiscal year, if changed since last report.
| Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. Yes [x] No . . . |
| Indicate by check mark whether the registrant is an accelerated filer (as defined in Rule 12b-2 of the Act) |
| Yes [x] No . . . Registrant’s number of common shares outstanding as of May 9, 2003: 26,133,217 |
FRONTIER OIL CORPORATION
QUARTERLY REPORT ON FORM 10-Q/A
FOR THE QUARTER ENDED MARCH 31, 2003
INDEX
Part I - Financial Information
Part II - Other Information
Frontier Oil Corporation is filing this amendment to its Quarterly Report on Form 10-Q/A for the quarter ended March 31, 2003, originally filed on May 15, 2003, in response to comments received from the Securities and Exchange Commission. This amendment to the original Form 10-Q amends and restates the original Form 10-Q. Frontier Oil Corporation has not updated the disclosure in this amendment to speak as of a later date. All information contained in this amendment and the original Form 10-Q is subject to updating and supplementing as provided in the period reports filed subsequent to the original filing date with the Securities and Exchange Commission.
This Form 10-Q/A contains “forward-looking statements,” as defined by the Securities and Exchange Commission. Such statements are those concerning contemplated transactions and strategic plans, expectations and objectives for future operations. These include, without limitation:
| • | statements, other than statements of historical facts, that address activities, events or developments that we expect, believe or anticipate will or may occur in the future; | |
| • | statements relating to future financial performance, future equity issuances and other matters; and | |
| • | any other statements preceded by, followed by or that include the words “anticipates,” “believes,” “expects,” “plans,” “intends,” “estimates,” “projects,” “could,” “should,” “may,” or similar expressions. |
Although we believe that our plans, intentions and expectations reflected in or suggested by the forward-looking statements we make in this Form 10-Q/A are reasonable, we can give no assurance that such plans, intentions or expectations will be achieved. These statements are based on assumptions made by us based on our experience and perception of historical trends, current conditions, expected future developments and other factors that we believe are appropriate in the circumstances. Such statements are subject to a number of risks and uncertainties, many of which are beyond our control. You are cautioned that any such statements are not guarantees of future performance and that actual results or developments may differ materially from those projected in the forward-looking statements.
We undertake no obligation to update or revise publicly any forward-looking statements, whether as a result of new information, future events or otherwise.
Definitions of Terms
bbl(s) = barrel(s)
bpd = barrel(s) per day
PART I - FINANCIAL INFORMATION
FRONTIER OIL CORPORATION AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF OPERATIONS
(Unaudited, in thousands except per share amounts)
For the three months ended March 31, 2003 2002
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Revenues:
Refined products $ 497,721 $ 334,985
Other 1,663 1,365
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499,384 336,350
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Costs and Expenses:
Raw material, freight and other costs 435,304 276,239
Refinery operating expenses, excluding depreciation 51,311 43,039
Selling and general expenses, excluding depreciation 4,678 3,803
Depreciation 6,960 6,598
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498,253 329,679
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Operating Income 1,131 6,671
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Interest expense and other financing costs 7,426 6,777
Interest income (373) (465)
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7,053 6,312
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Income (Loss) Before Income Taxes (5,922) 359
Provision (Benefit) For Income Taxes (2,222) 98
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Net Income (Loss) $ (3,700) $ 261
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Basic Earnings (Loss) Per Share of Common Stock $ (.14) $ .01
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Diluted Earnings (Loss) Per Share of Common Stock $ (.14) $ .01
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The accompanying notes are an integral part of these consolidated financial statements.
FRONTIER OIL CORPORATION AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS)
(Unaudited, in thousands)
For the three months ended March 31, 2003 2002
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Net Income (Loss) $ (3,700) $ 261
Other Comprehensive Income, Net of Income Tax:
Unrealized net losses on cash flow hedges, net of taxes of $21 - (33)
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Comprehensive Income (Loss) $ (3,700) $ 228
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The accompanying notes are an integral part of these consolidated financial statements.
FRONTIER OIL CORPORATION AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
(Unaudited, in thousands except shares)
March 31, 2003 and December 31, 2002 2003 2002
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ASSETS
Current Assets:
Cash, including cash equivalents of
$112,821 in 2003 and $109,825 in 2002 $ 113,931 $ 112,364
Trade receivables, net of allowance of $500 in both years 52,778 81,154
Note receivable, net of allowance of $800 1,449 1,449
Other receivables 1,371 987
Inventory of crude oil, products and other 145,285 105,160
Deferred tax current assets 2,243 5,346
Other current assets 2,001 2,510
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Total current assets 319,058 308,970
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Property, Plant and Equipment, at cost:
Refineries and pipeline 455,764 447,948
Furniture, fixtures and other equipment 5,173 5,119
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460,937 453,067
Less - Accumulated depreciation 151,087 144,127
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309,850 308,940
Asset held for sale 472 472
Other Assets 9,444 10,495
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TOTAL ASSETS $ 638,824 $ 628,877
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LIABILITIES AND SHAREHOLDERS' EQUITY
Current Liabilities:
Accounts payable $ 168,041 $ 174,917
Revolving credit facility 29,100 -
Accrued turnaround cost 3,343 12,849
Accrued liabilities and other 10,375 9,095
Accrued interest 7,976 3,856
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Total current liabilities 218,835 200,717
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Long-Term Debt 208,013 207,966
Long-Term Accrued Turnaround Cost 15,687 14,013
Post-Retirement Employee Liabilities 18,991 18,784
Deferred Credits and Other 4,230 3,963
Deferred Income Taxes 9,783 15,176
Commitments and Contingencies
Shareholders' Equity:
Preferred stock, $100 par value, 500,000 shares authorized,
no shares issued - -
Common stock, no par, 50,000,000 shares authorized,
30,309,249 and 30,290,324 shares issued in 2003 and 2002 57,471 57,469
Paid-in capital 102,761 102,557
Retained earnings 44,615 49,621
Accumulated other comprehensive income (loss) (598) (598)
Treasury stock, 4,176,035 shares and 4,151,210 shares
in 2003 and 2002 (38,387) (37,959)
Deferred employee compensation (2,577) (2,832)
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Total Shareholders' Equity 163,285 168,258
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TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY $ 638,824 $ 628,877
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The accompanying notes are an integral part of these consolidated financial statements.
FRONTIER OIL CORPORATION AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CASH FLOWS
(Unaudited, in thousands)
For the three months ended March 31, 2003 2002
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OPERATING ACTIVITIES
Net income (loss) $ (3,700) $ 261
Depreciation 6,960 6,598
Deferred income taxes (2,222) (231)
Deferred credits and other 1,620 727
Change in working capital from operations (21,997) (17,399)
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Net cash used in operating activities (19,339) (10,044)
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INVESTING ACTIVITIES
Additions to property, plant and equipment and other (6,607) (8,135)
El Dorado refinery acquisition - contingent earn-out payment - (7,500)
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Net cash used in investing activities (6,607) (15,635)
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FINANCING ACTIVITIES
Refining credit facility borrowings 29,100 30,400
Issuance of common stock 138 1,257
Purchase of treasury stock (428) (787)
Dividends (1,297) (1,279)
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Net cash provided by financing activities 27,513 29,591
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Increase in cash and cash equivalents 1,567 3,912
Cash and cash equivalents, beginning of period 112,364 103,995
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Cash and cash equivalents, end of period $ 113,931 $ 107,907
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The accompanying notes are an integral part of these consolidated financial statements.
FRONTIER OIL CORPORATION AND SUBSIDIARIES
NOTES TO INTERIM CONSOLIDATED FINANCIAL STATEMENTS
March 31, 2003
(Unaudited)
The consolidated financial statements include the accounts of Frontier Oil Corporation, a Wyoming corporation, and its wholly owned subsidiaries, including Frontier Holdings Inc., collectively referred to as Frontier or the Company. The Company is an energy company engaged in crude oil refining and wholesale marketing of refined petroleum products (the “refining operations”). The Company operates refineries (“the Refineries”) in Cheyenne, Wyoming and El Dorado, Kansas with a combined crude oil capacity of over 156,000 barrels per day. All of the operations of the Company are in the United States with its marketing efforts focused in the Rocky Mountain and Plains States regions of the United States. The Company purchases the crude oil to be refined and markets the refined petroleum products produced, including various grades of gasoline, diesel fuel, jet fuel, asphalt, chemicals and petroleum coke. The operations of refining and marketing of petroleum products are considered part of one reporting segment.
These financial statements have been prepared by the Company without audit, pursuant to the rules and regulations of the Securities and Exchange Commission and include all adjustments (comprised of only normal recurring adjustments) which are, in the opinion of management, necessary for a fair presentation. Certain information and footnote disclosures normally included in financial statements prepared in accordance with accounting principles generally accepted in the United States have been condensed or omitted pursuant to such rules and regulations, although the Company believes that the disclosures are adequate to make the information presented not misleading. It is suggested that the financial statements included herein be read in conjunction with the financial statements and the notes thereto included in the Company’s annual report on Form 10-K/A for the year ended December 31, 2002.
Basic earnings per share (“EPS”) has been computed based on the weighted average number of common shares outstanding. Basic and diluted shares were the same for the three months ended March 31, 2003 because a loss was incurred. Diluted earnings per share for the three months ended March 31, 2002 assumes the additional dilution for restricted stock and the exercise of in-the-money stock options. No adjustments to income are used in the calculation of earnings per share. The basic and diluted average shares outstanding are as follows:
Three Months Ended
March 31,
2003 2002
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Basic 25,863,844 25,626,451
Diluted 25,863,844 27,024,382
The number of shares of the Company’s restricted stock that could potentially dilute basic EPS in the future but were not included in the computation of diluted EPS for the quarters ended March 31, 2003 and 2002 were 182,279 and 203,980 shares, respectively, because to do so would have been antidilutive for the periods presented.
In June 2001, the Financial Accounting Standards Board (“FASB”) issued Statement of Financial Accounting Standard (“SFAS”) No. 143, “Accounting for Asset Retirement Obligations”. This statement provides accounting and disclosure requirements for retirement obligations associated with long-lived assets and became effective January 1, 2003. SFAS No. 143 requires that the fair value of a liability for an asset retirement obligation be recognized in the period in which it is incurred with the associated asset retirement costs being capitalized as a part of the carrying amount of the long-lived asset. SFAS No. 143 also includes disclosure requirements that provide a description of asset retirement obligations and reconciliation of changes in the components of those obligations. We have potential asset retirement obligation (“ARO”) liabilities related to our Refineries as a result of environmental and other legal requirements. Any ARO liability is not currently estimatable as to amount and timing, but we will continue to monitor and evaluate our potential AROs. In the event that we decide to cease the use of a particular refinery, an ARO liability would be recorded at that time. The adoption of SFAS No. 143 on January 1, 2003 did not have any impact on our current financial condition or results of operations.
In 2001, the American Institute of Certified Public Accountants (“AICPA”) issued an Exposure Draft for a Proposed Statement of Position, “Accounting for Certain Costs and Activities Related to Property, Plant and Equipment”. The proposed Statement of Position (“SOP”), as originally written, would require major maintenance activities, such as refinery turnarounds, to be expensed as costs are incurred. In the fourth quarter of 2002, the AICPA announced it would be transitioning this project to the FASB, although the AICPA may retain and address certain components of the proposed SOP. The FASB and the AICPA have not determined which components, if any, will be retained by the AICPA for potential issuance in a future SOP. In addition, the FASB has not set a timetable for addressing the issues raised by the proposed SOP. Adoption of the proposed SOP would require that any existing turnaround accruals be reversed to income immediately and the costs of future turnarounds expensed as incurred. If this proposed change were in effect at March 31, 2003, the Company would have been required to reverse the turnaround accruals and recognize pretax income totaling $19.0 million. The total accrued turnaround costs will change throughout the year as turnarounds are incurred and accruals are made for future turnarounds. If adopted in its present form, income related to this proposed change would be reported as a cumulative effect of an accounting change, net of tax, in the consolidated statements of operations.
In April 2002, the FASB issued SFAS No. 145, “Rescission of FASB Statements No. 4, 44 and 64, Amendment of FASB Statement No. 13, and Technical Corrections.” It is probable that the rescission of SFAS No. 4 is the only portion of SFAS No. 145 that may have an impact on us in the future. Under SFAS No. 4, all gains and losses from extinguishment of debt were required to be aggregated and, if material, classified as an extraordinary item, net of related income tax effect. SFAS No. 145 eliminates SFAS No. 4. As a result, gains and losses from extinguishment of debt should be classified as extraordinary items only if they meet the criteria in Opinion 30. We adopted SFAS No. 145 effective January 1, 2003, and it did not have any impact on our financial condition or results of operations.
2. Schedule of major components of inventory
March 31, December 31,
2003 2002
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(in thousands)
Crude oil $ 57,064 $ 33,765
Unfinished products 37,318 24,806
Finished products 31,362 29,836
Process chemicals 6,079 3,308
Repairs and maintenance supplies and other 13,462 13,445
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$ 145,285 $ 105,160
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Inventories of crude oil, unfinished products and all finished products are recorded at the lower of cost on a first in, first out (“FIFO”) basis or market. Crude oil includes both domestic and foreign crude oil volumes at its cost and associated freight and other cost. Unfinished products (work in process) include any crude oil which has entered into the refining process, and other feedstocks that are not finished as far as refining operations are concerned. These include unfinished gasoline and diesel, blendstocks and other feedstocks. Finished product inventory includes saleable gasoline, diesel, jet fuel, chemicals, asphalt and other finished products. Unfinished and finished products inventory values have both components of raw material, the associated raw material freight and other costs, and direct refinery operating expense allocated when refining begins relative to their proportionate market values. Refined product exchange transactions are considered asset exchanges with deliveries offset against receipts. The net exchange balance is included in inventory. Inventories of materials and supplies and process chemicals are recorded at the lower of average cost or market.
Stock-based compensation is measured in accordance with Accounting Principles Board (“APB”) Opinion No. 25. Under this intrinsic value method, compensation cost is the excess, if any, of the quoted market value of the Company’s common stock at the grant date over the amount the employee must pay to acquire the stock.
On March 13, 2001 the Company established the Frontier Oil Corporation Restricted Stock Plan (the “Plan”) which reserved 1,000,000 shares of common stock held as treasury stock by the Company for restricted stock grants to be made under an incentive compensation program. Restricted shares, when granted, are recorded at the market value on the date of issuance as deferred employee compensation (equity account) and amortized to compensation expense over the respective vesting periods of the stock. Compensation costs of $255,000 and $125,000 related to restricted stock awards were recognized for the three months ended March 31, 2003 and 2002, respectively. As of March 31, 2003, there were 205,629 shares of unvested restricted stock, which represents the total of grants made in 2001 and 2002 less the vested portion of the grants and shares forfeited from employee departures prior to vesting. The remaining 123,054 shares from the 2001 grants vest in March 2004. Of the remaining 82,575 shares from the 2002 grants, approximately 27,527 shares will vest in March 2004 with the remaining vesting in March 2005. No grants were made in 2003 through March 31.
The Company has stock option plans which authorize the granting of options to employees to purchase shares of the Company’s common stock. The plans through March 31, 2003 had reserved for issuance a total of 8,002,075 shares of common stock of which 4,454,100 shares were granted and exercised, 3,406,325 shares were granted and were outstanding and 141,650 shares were available to be granted. Options under the plans are granted at fair market value on the date of grant. No entries are made in the accounts until the options are exercised, at which time the proceeds are credited to common stock and paid-in capital. Generally, the options vest ratably throughout their one- to five-year terms.
Had compensation costs been determined based on the fair value at the grant dates for awards, the Company’s net income (loss) and EPS would have been the pro forma amounts indicated in the following table for the three months ended March 31, 2003 and 2002:
2003 2002
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(in thousands)
Net income (loss) as reported $ (3,700) $ 261
Pro forma compensation expense, net of tax (3,609) 261
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Pro forma net loss $ (7,309) $ 261
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Basic EPS:
As reported $ (.14) $ .01
Pro forma (.28) .01
Diluted EPS:
As reported $ (.14) $ .01
Pro forma (.28) .01
The Company, at times, enters into commodity derivative contracts to manage its price exposure to its inventory positions, purchases of foreign crude oil and consumption of natural gas in the refining process or to fix margins on certain future production. The commodity derivative contracts used by the Company may take the form of futures contracts, collars or price swaps and are entered into with counterparties believed to be credit-worthy. The Company uses futures transactions to price foreign crude oil cargos at the price at the time the crude oil is processed by the El Dorado refinery instead of the price when purchased. Foreign crude oil delivery times can exceed one month from when the purchase is made. The Company accounts for its commodity derivative contracts under 1) the hedge (or deferral) method of accounting when the derivative contracts are designated as hedges for accounting purposes, or 2) mark-to-market accounting if the Company elects not to designate derivative contracts as accounting hedges or if such derivative contracts do not qualify for hedge accounting. As such, gains or losses on commodity derivative contracts accounted for as hedges are recognized in refining operating costs when the associated transactions are consummated while gains and losses on transactions accounted for using mark –to-market accounting are reflected in other revenues at each period end.
Other revenues for the three months ended March 31, 2003 includes $1.4 million realized and unrealized net gains on derivative contracts accounted for using mark-to-market accounting.
At March 31, 2003 the Company had the following open commodity derivative contracts which, while economic hedges, did not qualify for hedge accounting treatment and whose gains or losses are being reflected in other revenues:
| • | Derivative contracts on 191,000 barrels of crude oil to hedge gas oil inventory builds which resulted from the March 2003 turnaround at the El Dorado refinery. These open contracts have total unrealized gains at March 31, 2003 of approximately $562,000. During the three months ended March 31, 2003 the Company realized net gains of approximately $633,000 on closed out contracts to hedge the gas oil inventory. | |
| • | Derivative contracts on 155,000 barrels of crude oil to hedge crude oil inventory builds which resulted from the March 2003 turnaround at the El Dorado refinery. These open contracts have total unrealized gains at March 31, 2003 of approximately $164,000. |
The Company had no open derivative contracts at March 31, 2003 being accounted for as hedges. During the three months ended March 31, 2003, the Company had the following derivatives that were appropriately designated and accounted for as hedges:
| • | Natural Gas Collars. Price swaps on natural gas for the purpose of hedging against natural gas price increases for February and March 2003 for approximately 100% of the El Dorado refinery’s anticipated usage and which are accounted for as cash flow hedges. The February group of contracts to hedge natural gas costs were for 700,000 MMBTU and expired with no gain or loss. The March group of contracts to hedge natural gas totaled 720,000 MMBTU and the Company realized a $1.7 million gain which reduced refining operating costs in March. | |
| • | Crude Contracts.In January 2003, the Company had derivative contracts on 200,000 barrels of crude oil to hedge Canadian crude costs for the Cheyenne refinery which were accounted as fair value hedges. A $13,000 loss was realized on these positions of which $31,000 increased crude costs and $18,000 income was reflected in other revenues for the ineffective portion of this hedge. |
The Company’s refining and marketing operations are subject to a variety of federal, state and local health and environmental laws and regulations governing product specifications, the discharge of materials into the environment, and the generation, treatment, storage, transportation and disposal of solid and hazardous waste and materials. Numerous permits with varying terms of duration are required for the operation of the Refineries, and these permits are subject to revocation, expiration, modification and renewal. Timely application for new permits and/or renewal of existing permits is undertaken as necessary to maintain compliance with applicable permitting requirements. Governmental authorities have the power to enforce compliance with these regulations and permits, and violators are subject to injunctions, civil fines and even criminal penalties. The Company believes that each of our Refineries has obtained all necessary permits and is in substantial compliance with such permits, and other applicable existing environmental laws and regulations.
The Company’s operations and many of the products manufactured are specifically subject to certain requirements of the Clean Air Act (“CAA”) and related state and local regulations. The 1990 amendments to the CAA contain provisions that will require capital expenditures for the installation of certain air pollution control devices at our refineries during the next several years. The EPA recently embarked on a Petroleum Refining Initiative (“Initiative”) alleging industry-wide noncompliance with certain CAA rules. The Initiative has resulted in many refiners entering into consent decrees typically requiring substantial expenditures for penalties and additional pollution control equipment. Frontier has been contacted by the EPA and invited to meet with them to hear more about the Initiative. At this time, the Company does not know how or if the Initiative will affect Frontier. The Company has, however, recently determined that over the next three years, expenditures totaling approximately $10 million may be necessary to further reduce emissions from the Refineries’ flare systems. Because other refineries will be required to make similar expenditures, Frontier does not expect such expenditures to materially adversely impact the Company’s competitive position.
On December 21, 1999, the EPA promulgated national regulations limiting the amount of sulfur that is to be allowed in gasoline. The total capital expenditures estimated, as of March 31, 2003, to achieve the final gasoline sulfur standard, are approximately $35 million at the Cheyenne Refinery and approximately $44 million at the El Dorado Refinery. Approximately $9.5 million of the Cheyenne Refinery expenditures had been incurred as of March 31, 2003, an additional $18.5 million is expected to be incurred by early 2004 with the remaining $7 million in 2009 and 2010. The expenditures for the El Dorado Refinery are expected to be incurred beginning in 2008 and completed in 2010.
The EPA recently promulgated regulations that will limit the sulfur content of highway diesel fuel beginning in 2006 to 15 parts-per-million from the current standard of 500 parts-per-million. As of March 31, 2003, capital costs for diesel desulfurization are estimated to be approximately $5 million for Cheyenne and $56 million for El Dorado. The Cheyenne Refinery expenditures are currently expected to be committed beginning in 2005, with the majority to be committed in 2006. Approximately $6 million of the El Dorado Refinery expenditures are currently expected to be committed in 2004 with the remaining $50 million in 2005 and 2006.
On April 15, 2003, the EPA proposed regulations to reduce emissions from diesel engines used in off-road activities such as agriculture, mining and railroads and also to limit the allowable amount of sulfur in the diesel fuel used in those engines. If promulgated, the EPA’s proposal would require a reduction in off-road diesel fuel sulfur by June 1, 2007 from the currently allowable 5000 parts per million to 500 parts per million and by June 1, 2010 further limit the concentration of diesel fuel used off-road applications other than railroads and marine engines to 15 parts per million of sulfur. The EPA is also proposing to allow small business refiners, such as Frontier, to continue to produce off-road diesel at the current sulfur limit of 5000 parts per million through May 31, 2010 and to meet a limit of 500 parts per million sulfur from June 1, 2010 until May 31, 2014. Frontier has historically provided a minor amount of diesel fuel to the off-road markets from both of the Company’s refineries. The Company is monitoring these regulatory developments and is evaluating its compliance options. The costs that the Company will eventually incur to comply with these regulations, when final, are currently unknown.
As is the case with all companies engaged in similar industries, the Company faces potential exposure from future claims and lawsuits involving environmental matters. The matters include soil and water contamination, air pollution, personal injury and property damage allegedly caused by substances which the Company manufactured, handled, used, released or disposed of.
One of the Company’s subsidiaries owned and operated an interest in an oil field in the Los Angeles metropolitan area from 1985 to 1995. The production facilities for the oil field are located on the campus of the Beverly Hills high school. In April 2003, a law firm filed claims with the Beverly Hills school district and city on behalf of approximately 23 former students, alleging that emissions from the oil field or production facilities caused cancers in those individuals. Subsequently, public media reported that the law firm filed approximately 200 additional claims on behalf of former students, school employees and area residents claiming that various health problems were caused by the alleged emissions. According to a newspaper article, the law firm said it expected to file lawsuits against several oil companies in addition to the claims filed against the school district and city. The oil production site operated by Frontier’s subsidiary was a modern facility and was operated with a high level of safety and responsibility. Frontier believes its subsidiary’s activities did not cause any health problems for former Beverly Hills high school students, school employees or area residents. Frontier believes that neither the claims that have been made against the Beverly Hills school district and city nor future litigation by which similar claims may be asserted against Frontier’s subsidiary will result in any material liability or have any other material adverse effect upon Frontier.
Cheyenne Refinery. The Company is party to an agreement with the State of Wyoming requiring the investigation and possible eventual remediation of certain areas of the Cheyenne Refinery’s property which may have been impacted by past operational activities. This action primarily addressed the threat of groundwater and surface water contamination. Based upon the results of the investigation, substantial capital expenditures and remediation of conditions found to exist have already taken place or are in progress, including the completion of surface impoundment closures, waste stabilization activities and other site remediation projects totaling approximately $4 million and an ongoing groundwater remediation program averaging $150,000 in annual operation and maintenance costs. Additional remedial action could be required by a subsequent administrative order or permit.
El Dorado Refinery. The El Dorado Refinery is subject to a 1988 consent order with the Kansas Department of Health and the Environment (“KDHE”). This order, including various subsequent modifications, requires the Refinery to continue the implementation of a groundwater management program with oversight provided by the KDHE Bureau of Environmental Remediation. The order requires that remediation activities continue until KDHE-established groundwater criteria or other criteria agreed to by the KDHE and the Refinery are met. Frontier acquired the El Dorado refinery in November 1999 from Equilon Enterprises LLC, now known as Shell Oil Products US (“Shell”). Subject to the terms of the purchase and sale agreement, Shell will be responsible for the costs of continued compliance with this order.
The most recent National Pollutant Discharge Elimination System permit issued to the El Dorado Refinery requires, in part, the preparation and submittal of an engineering report identifying certain refinery wastewater treatment plant upgrades necessary to allow routine compliance with applicable discharge permit limits. In accordance with the provisions of the purchase and sale agreement, Shell will be responsible for the first $2 million of any required wastewater treatment system upgrades. If required system upgrade costs exceed this amount, Shell and Frontier will share, based on a sliding scale percentage, up to another $3 million in upgrade costs. Subject to the terms of the purchase and sale agreement, Shell will be responsible for up to $5 million in costs, in addition to Shell’s obligation for the wastewater treatment system upgrade, relating to safety, health and environmental conditions after closing arising from Shell’s operation of the El Dorado Refinery that are not covered under a ten-year insurance policy. This insurance policy has $25 million coverage through November 17, 2009 for environmental liabilities, with a $500,000 deductible, and will reimburse the Company for losses related to all known and some unknown conditions existing prior to our acquisition of the El Dorado Refinery. The first phase of wastewater treatment system upgrades was completed in 2001 at a cost of $2.6 million with payment apportioned as described above.
On August 18, 2000, the Company entered into a Consent Agreement and Final Order of the Secretary (“Agreement”) with the KDHE that required the initiation of a wastewater toxicity testing program to commence upon the completion of the wastewater treatment upgrades described above. Progress has been made toward satisfying the provisions of the Agreement, and Frontier expects to meet all applicable requirements.
On March 31, 2003 the Company announced that it had entered into an agreement with Holly Corporation (“Holly”) pursuant to which the two companies will merge. Following the merger, the combined entity will own five refineries with refining capacity in excess of 260,000 barrels per day by the end of 2003. Pursuant to the merger agreement, Holly stockholders will receive in the merger transaction approximately 37% of the outstanding shares of the combined company, $172.5 million in cash, and contingent value rights representing non-transferable interests in potential future net recoveries from litigation related to past sales of jet fuel by Holly to the United States government. Frontier shareholders will receive in the merger transaction approximately 63% of the outstanding shares of the combined company, which will be named Frontier Oil Corporation. The combined company’s shares are expected to be listed on the New York Stock Exchange under the symbol “FTO”. The boards of directors of both companies have unanimously approved the merger and Frontier and Holly will each hold a special meeting of stockholders to consider and vote on the merger agreement. A registration statement on Form S-4 relating to the merger was filed on May 13, 2003. Consummation of the transaction is expected in the third quarter of 2003.
On April 17, 2003, the Company received the net proceeds from a private placement of $220 million of 8% senior notes (“Senior Notes”) due April 15, 2013. The net proceeds of the Senior Notes will be used, together with other available funds, to finance the cash portion of the merger with Holly, to pay related fees and expenses and to refinance or pay off existing Holly indebtedness. Any remaining net proceeds will be used for other general corporate purposes, which may include capital expenditures, potential future acquisitions or the repayment of our existing indebtedness. The Senior Notes were issued at 99.156% of principal amount, and were issued by Frontier Escrow Corporation, a newly formed, wholly-owned, direct subsidiary of Frontier Oil Corporation that was created solely to issue the Senior Notes and to merge with and into Frontier Oil Corporation upon consummation of the Holly merger. Pending consummation of the merger with Holly, the net proceeds of the notes offering, along with other amounts contributed by the Company, have been placed in an escrow account. If the merger with Holly does not occur by October 31, 2003, the notes will be redeemed by Frontier Escrow Corporation at a price equal to 101% of the aggregate principal amount of the notes plus accrued interest.
| ITEM 2. | MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS |
RESULTS OF OPERATIONS
The terms “Frontier” and “we” refer to Frontier Oil Corporation and its subsidiaries.
Three months ended March 31, 2003 compared with the same period in 2002
We had a net loss for the three months ended March 31, 2003 of $3.7 million, or ($.14) per share, compared to net income of $261,000, or $.01 per diluted share, for the same period in 2002. The most significant factor causing the $4.0 million decrease in the results of operations in 2003 from 2002 was higher natural gas costs which increased refinery operating expenses.
Operating income decreased $5.5 million in 2003 versus 2002 due to increases in raw material, freight and other costs of $159.0 million, refinery operating expenses, excluding depreciation, of $8.3 million (primarily due to natural gas costs) and increases in selling and general costs, excluding depreciation of $875,000 and depreciation of $362,000, offset by an increase in refined product revenues of $162.7 million and an increase in other revenues of $298,000. The major economic and operating factors affecting operating income were higher light product margins in 2003 as compared to 2002 and increases in both the light/heavy (the discount at which heavy crude oil sells compared to the sales price of light crude oil) and WTI/WTS (the difference between West Texas Intermediate and West Texas Sour crude oil prices) crude spreads, offset by the negative impacts of the 18 day planned major turnaround in March 2003 at our El Dorado refinery and a lower positive inventory valuation impact during the three months ended March 31, 2003 compared to the same period in 2002.
Refined product revenues increased $162.7 million or 49% due to increased sales prices offset by decreased overall sales volumes. Refined products revenues are impacted by changes in the price of crude oil as product sales prices generally change accordingly. The average price of crude oil was substantially higher in 2003 than in 2002. Average gasoline prices increased from $27.07 per sales barrel for the first quarter of 2002 to $41.11 per sales barrel during the first quarter of 2003. Gasoline sales volumes decreased 3,334 barrels per day during the quarter ended March 31, 2003 compared to the comparable quarter in 2002. Average diesel and jet fuel prices for the first quarter of 2003 increased from $24.28 per sales barrel for the first quarter of 2002 to $40.88 per sales barrel for the first quarter of 2003. Diesel sales volumes decreased 6,702 barrels per day during the quarter ended March 31, 2003 compared to the comparable quarter in 2002. Manufactured product yields (“yields”) are the volumes of specification materials that are obtained through the distilling of crude oil and operations of other refinery process units. Yields of gasoline decreased 7,490 barrels per day or 9% from 82,104 barrels per day in 2002 to 74,614 barrels per day in 2003 while yields of diesel and jet fuel decreased 8,513 barrels per day or 17% from 51,273 barrels per day in 2002 to 42,760 barrels per day in 2003. The primary reason for the lower volumes in sales and yields in 2003 was the turnaround at the El Dorado refinery which commenced on March 18, 2003 and was completed on March 30.
Other revenues increased $298,000 to $1.7 million in 2003 due to $1.4 million income from realized and unrealized futures trading net gains on inventories in 2003 compared to a $1.1 million gain from the ineffective portion of foreign crude oil hedges in 2002.
Raw material, freight and other costs include crude oil and other raw materials utilized in the refining process, purchased products and blendstocks, freight costs for FOB destination sales, as well as the impact of changes in inventory under FIFO inventory accounting. Raw material costs are impacted by changes in the price of crude oil. The average price of crude oil was substantially higher in 2003 than in 2002. Raw material, freight and other costs of $435.3 million during the three months ending March 2003 increased 67% or $13.43 per sales barrel when compared to the same period in 2002 primarily due to higher crude oil prices. For the three months ended March 31, 2003, we realized a decrease in raw material, freight and other costs as a result of inventory gains of approximately $5.2 million after tax ($8.4 million pretax, comprised of $3.0 million from the Cheyenne refinery and $5.4 million from the El Dorado refinery). This was the net result of inventory gains in January and February because of increasing crude and product prices, partially offset by inventory losses (including lower of cost or market adjustments to inventory of $11.6 million) during March because of decreasing crude and product prices. The lower of cost or market adjustment at El Dorado at March 31, 2003 was exacerbated due to the turnaround and rapid price declines at the end of March. For the three months ended March 31, 2002 we realized an increase in the raw material, freight and other costs from inventory gains of approximately $8.6 million after tax ($13.9 million pretax, comprised of $4.7 million from the Cheyenne refinery and $9.2 million from the El Dorado refinery) because of increasing crude prices during the quarter. The Cheyenne refinery raw material, freight and other costs of $32.09 per sales barrel increased 65% from $19.48 per sales barrel in 2002 due to higher crude oil prices. Our profitability at our Cheyenne refinery is also linked to the light/heavy crude spread. We benefited from the light/heavy spread averaging $6.27 per barrel in the first three months of 2003 compared to only $3.75 per barrel in the first three months of 2002. The heavy crude oil utilization rate at the Cheyenne refinery expressed as a percentage of total crude oil was 91% in both 2003 and 2002. The El Dorado refinery raw material, freight and other costs of $34.05 per sales barrel increased 69% from $20.11 per sales barrel in 2002 due to higher crude oil prices. Our profitability at our El Dorado refinery is linked to the WTI/WTS crude spread. The WTI/WTS spread increased from an average of $1.53 per barrel in the three months ended March 31, 2002 to $2.38 per barrel for the same period this year.
Refinery operating expenses, excluding depreciation, include both the variable costs (including energy and utilities) and the fixed costs (salaries, taxes, maintenance costs and other) of operating the refineries. Refinery operating expense, excluding depreciation, increased by $8.3 million (to $3.93 per sales barrel from $3.11 per sales barrel) during the three months ended March 31, 2003, when compared to the same period in 2002. Higher natural gas costs comprised approximately 40% of the per sales barrel refinery operating expense increase with the remainder being primarily due to decreased yields and sales volumes. The Cheyenne refinery operating expense, excluding depreciation, for the three months ended March 31, 2003 increased $1.3 million from the same period in 2002, due to a $1.1 million increase in natural gas costs; however refinery operating expense at Cheyenne decreased $.39 to $3.25 per sales barrel in 2003 due to increased sales volumes. The El Dorado refinery operating expense, excluding depreciation, increased $7.0 million for the three months ended March 31, 2003 from the same period in 2002 due primarily to a $3.5 million increase in natural gas cost, an increase of $1.7 million in salaries resulting from overtime incurred in connection with the turnaround and overall increased benefit costs, and the $700,000 turnaround expense in excess of accrual. Refinery operating expense at El Dorado increased to $4.29 per sales barrel for the three months ended March 31, 2003, compared to $2.92 per sales barrel in 2002, a combination effect of both the higher refinery operating expenses and decreased sales volumes in 2003 due to the turnaround.
Selling and general expenses, excluding depreciation, increased $875,000 or 23% for the three months ended March 31, 2003 compared to the same period in 2002 because of increased salaries, increased travel costs relating to company aircraft and engineering, legal and other consulting services relating to evaluating potential acquisitions.
Depreciation increased $362,000 or 5% in the 2003 three-month period as compared to the same period in 2002 because of increases in capital investments.
The interest expense increase of $649,000 or 10% for the three months ended March 31, 2003 was attributable to the write-off of deferred finance costs related to previous repurchases of Senior Notes offset by less interest expense on the revolving credit facility from both lower average borrowings and lower market interest rates this year. Average debt for the three months ended March 31, decreased from $246 million in 2002 to $229 million in 2003.
LIQUIDITY AND CAPITAL RESOURCES
Net cash used by operating activities for the three months ended March 31, 2003 was $19.3 million compared to $10.0 million cash used by operating activities for the three months ended March 31, 2002. Working capital changes required $22.0 million and $17.4 million of cash flows for the first three months of 2003 and 2002, respectively. The major use of working capital during the three months ended March 31, 2003 were increases in inventory of $40.1 million due to higher crude and other prices. The major source of working capital during the three months ended March 31, 2003 was a decrease in receivables of $28.0 million due to low El Dorado refinery sales in March because of the turnaround and timing of cash receipts.
At March 31, 2003, we had borrowings under our revolving credit facility of $29.1 million, $113.9 million of cash and cash equivalents, working capital of $100.2 million, and an $82.3 million borrowing base availability for additional borrowings under our revolving credit facility.
Additions to property and equipment in the first three months of 2003 of $6.6 million decreased $9.0 million from the first three months in 2002 which included the $7.5 million El Dorado earn-out payment. Capital expenditures of approximately $41 million are planned in 2003, which includes nearly $14.0 million for the low sulfur gasoline project at Cheyenne. The additional $27.0 million of capital expenditures consists of $13.6 million of sustaining capital (including safety, environmental and operational projects), $6.9 million of growth, strategic and profitability projects, $3.3 million of information technology projects and $3.2 million of small capital and other projects at both the Cheyenne and El Dorado refineries. The $41.0 million of expenditures planned for 2003 does not include any amount for an El Dorado earn-out payment, as none was earned in 2002.The planned capital expenditures in excess of $35.0 million will be subject to bank approval or amendment under our revolving credit facility or we may have the option to lease a portion of the equipment required for the Cheyenne refinery low sulfur gasoline project. We are currently in the process of renegotiating our revolving credit facility, which would allow our planned level of capital expenditures and provide additional line of credit capacity upon consummation of our merger with Holly.
During the first quarter of 2003 we have not purchased any additional common stock under our previously announced stock repurchase programs authorized by our Board of Directors to purchase up to six million shares, however, we did acquire 24,825 shares of stock from employees to cover their withholding taxes on shares of restricted stock which vested in March. Through December 2002, 4,367,366 shares of common stock had been purchased under the stock repurchase programs.
Dividends of $1.3 million were paid to shareholders during the first three months of 2003. These dividends of $.05 per share were declared in December 2002 and were paid on January 13, 2003. Our Board of Directors also declared dividends of $.05 per share, which were paid on April 14, 2003 to shareholders of record on March 28, 2003. The cash required for this dividend was approximately $1.3 million and was accrued as of March 31, 2003.
On April 17, 2003, we received the net proceeds from a private placement of $220 million of 8% senior notes (“Senior Notes”) due April 15, 2013. The net proceeds of the Senior Notes will be used, together with other available funds, to finance the cash portion of the previously discussed Holly merger, to pay related fees and expenses and to refinance or pay off existing Holly indebtedness. Any remaining net proceeds will be used for other general corporate purposes which may include capital expenditures, potential future acquisitions or the repayment of our existing indebtedness. The Senior Notes were issued at 99.156% of principal amount and were issued by Frontier Escrow Corporation, a newly formed, wholly-owned, direct subsidiary of Frontier that was created solely to issue the Senior Notes and to merge with and into Frontier Oil Corporation upon consummation of the Holly merger. Pending consummation of the Holly merger, the net proceeds of the offering, along with other amounts contributed by us, have been placed in an escrow account. If the Holly merger does not occur by October 31, 2003, the Senior Notes will be redeemed by Frontier Escrow Corporation at a price equal to 101% of the aggregate principal amount of the notes plus accrued interest.
Consolidated: Three Months Ended
March 31,
---------------------------------
2003 2002
-------------- --------------
Charges (bpd) (1)
Light crude 26,576 31,388
Heavy and intermediate crude 97,699 108,607
Other feed and blend stocks 20,549 17,315
--------------- --------------
Total 144,824 157,310
Manufactured product yields (bpd) (2)
Gasoline 74,614 82,104
Diesel and jet fuel 42,760 51,273
Asphalt 5,382 4,483
Chemicals (1) 848 (52)
Other 17,792 16,916
--------------- --------------
Total 141,396 154,724
Total product sales (bpd)
Gasoline 83,032 86,366
Diesel and jet fuel 44,257 50,959
Asphalt 3,946 3,398
Chemicals (3) 848 319
Other 12,838 12,838
--------------- --------------
Total 144,921 153,880
Refinery operating margin information (per sales bbl)
Refined products revenue $ 38.16 $ 24.19
Raw material, freight and other costs (FIFO inventory accounting) 33.38 19.95
Refinery operating expenses, excluding depreciation 3.93 3.11
Refinery depreciation .54 .47
Average West Texas Intermediate crude oil price at Cushing, OK $ 34.78 $ 21.28
Average sales price (per sales bbl)
Gasoline $ 41.11 $ 27.07
Diesel and jet fuel 40.88 24.28
Asphalt 23.59 14.92
Chemicals (3) 64.82 35.10
Other 12.48 6.58
| (1) | Charges are the quantity of crude oil and other feedstocks processed through refinery units. |
| (2) | Manufactured product yields are the volumes of specification materials that are obtained through the distilling of crude oil and operations of other refinery process units. |
| (3) | During the first quarter of 2002, the process of shutting down the petro-chemical complex at El Dorado began and we discontinued the production of phenol and acetone and began producing and selling benzene. |
REFINING OPERATING STATISTICAL INFORMATION
Cheyenne Refinery: Three Months Ended
March 31,
--------------------------------
2003 2002
------------- -------------
Charges (bpd) (1)
Light crude 3,766 3,227
Heavy crude 38,458 32,616
Other feed and blend stocks 6,681 4,867
-------------- -------------
Total 48,905 40,710
Manufactured product yields (bpd) (2)
Gasoline 20,866 16,512
Diesel 14,093 12,640
Asphalt 5,382 4,483
Other 7,246 6,117
-------------- -------------
Total 47,587 39,752
Total product sales (bpd)
Gasoline 27,620 21,026
Diesel 13,877 11,802
Asphalt 3,946 3,398
Other 4,420 4,304
-------------- -------------
Total 49,863 40,530
Refinery operating margin information (per sales bbl)
Refined products revenue $ 38.31 $ 24.14
Raw material, freight and other costs (FIFO inventory accounting) 32.09 19.48
Refinery operating expenses, excluding depreciation 3.25 3.64
Refinery depreciation .85 .96 -------------- -------------
Average light/heavy crude spread based on
delivered crude costs (per bbl) (3) $ 6.27 $ 3.75
Average sales price (per sales bbl)
Gasoline $ 42.99 $ 28.87
Diesel 42.60 25.34
Asphalt 23.59 14.92
Other 8.78 4.97
| (1) | Charges are the quantity of crude oil and other feedstocks processed through refinery units. |
| (2) | Manufactured product yields are the volumes of specification materials that are obtained through the distilling of crude oil and operations of other refinery process units. |
| (3) | Average light/heavy spread is the discount at which heavy crude oil (gravity is low) sells compared to the sales price of light crude oil (gravity is high). |
REFINING OPERATING STATISTICAL INFORMATION
El Dorado Refinery: Three Months Ended
March 31,
--------------------------------
2003 2002
------------- -------------
Charges (bpd) (1)
Light crude 22,810 28,161
Heavy and intermediate crude 59,241 75,991
Other feed and blend stocks 13,868 12,449
-------------- -------------
Total 95,919 116,601
Manufactured product yields (bpd) (2)
Gasoline 53,748 65,592
Diesel and jet fuel 28,667 38,633
Chemicals (3) 848 (52)
Other 10,547 10,798
-------------- -------------
Total 93,810 114,971
Total product sales (bpd)
Gasoline 55,412 65,339
Diesel and jet fuel 30,380 39,157
Chemicals (3) 848 319
Other 8,417 8,534
-------------- -------------
Total 95,057 113,349
Refinery operating margin information (per sales bbl)
Refined products revenue $ 38.08 $ 24.21
Raw material, freight and other costs (FIFO inventory accounting) 34.05 20.11
Refinery operating expenses, excluding depreciation 4.29 2.92
Refinery depreciation .38 .29
WTI/WTS crude spread (per bbl) (4) $ 2.38 $ 1.53
Average sales price (per sales bbl)
Gasoline $ 40.17 $ 26.50
Diesel and jet fuel 40.09 23.96
Chemicals (3) 64.82 35.10
Other 14.43 7.39
| (1) | Charges are the quantity of crude oil and other feedstocks processed through refinery units. |
| (2) | Manufactured product yields are the volumes of specification materials that are obtained through the distilling of crude oil and operations of other refinery process units. |
| (3) | During the first quarter of 2002, the process of shutting down the petro-chemical complex at El Dorado began and we discontinued the production of phenol and acetone and began producing and selling benzene. |
| (4) | Average differential between benchmark West Texas intermediate (sweet) and West Texas sour crude oil prices. |
ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
Impact of Changing Prices.Our revenues and cash flows, as well as estimates of future cash flows, are very sensitive to changes in energy prices. Major shifts in the cost of crude oil and the price of refined products and natural gas can result in large changes in the operating margin from refining operations. These prices also determine the carrying value of the refineries’ inventories.
Price Risk Management Activities. At times, we enter into commodity derivative contracts to manage our price exposure to our inventory positions, our purchases of foreign crude oil and consumption of natural gas in the refining process as well as fix margins on certain future production. The commodity derivative contracts we use may take the form of futures contracts or price swaps and are entered into with reputable counterparties. We use futures transactions to price foreign crude oil cargos at the time when the crude oil is processed by the El Dorado Refinery instead of the price when purchased. Foreign crude oil delivery times can exceed one month from when the purchase is made. In addition, we may engage in futures transactions for the purchase of natural gas at fixed prices. The El Dorado and Cheyenne refineries consume natural gas for energy and feedstock purposes. We account for our commodity derivative contracts under 1) the hedge (or deferral) method of accounting when the derivative contracts qualify and are designated as hedges for accounting purposes, or 2) mark-to-market accounting if we elect not to designate derivative contracts as accounting hedges or if such derivative contracts do not qualify for hedge accounting. As such, gains or losses on commodity derivative contracts accounted for as hedges are recognized in refining operating costs when the associated transactions are consummated while gains and losses on transactions accounted for using mark-to-market accounting are reflected in other revenues at each period end.
Other revenues for the three months ended March 31, 2003 included $1.4 million realized and unrealized net gains on derivative contracts accounted for using mark-to market accounting.
At March 31, 2003 the Company had the following open commodity derivative contracts which, while economic hedges, did not qualify for hedge accounting treatment and whose gains or losses are being reflected in other revenues:
| • | Derivative contracts on 191,000 barrels of crude oil to hedge gas oil inventory builds which resulted from the March 2003 turnaround at our El Dorado refinery. These open contracts have total unrealized gains at March 31, 2003 of approximately $562,000. During the three months ended March 31, 2003 we realized net gains of approximately $633,000 on closed out contracts to hedge the gas oil inventory. | |
| • | Derivative contracts on 155,000 barrels of crude oil to hedge crude oil inventory builds which resulted from the March 2003 turnaround at the El Dorado refinery. These open contracts have total unrealized gains at March 31, 2003 of approximately $164,000. |
We had no open derivative contracts at March 31, 2003 which were being accounted for as hedges. During the three months ended March 31, 2003, we had the following derivatives which were appropriately designated and accounted for as hedges during the period:
| • | Natural Gas Collars. Price swaps on natural gas for the purpose of hedging against natural gas price increases for February and March 2003 for approximately 100% of the El Dorado refinery’s anticipated usage and which are accounted for as cash flow hedges. The February group of contracts to hedge natural gas costs were for 700,000 MMBTU and expired with no gain or loss. The March group of contracts to hedge natural gas totaled 720,000 MMBTU and we realized a $1.7 million gain which reduced refining operating costs in March. | |
| • | Crude Contracts.In January 2003, we had derivative contracts on 200,000 barrels of crude oil to hedge Canadian crude costs for our Cheyenne refinery which were accounted as fair value hedges. A $13,000 loss was realized on these positions of which $31,000 increased crude costs and $18,000 income was reflected in other revenues for the ineffective portion of this hedge. |
Interest Rate Risk. Borrowings under our revolving credit facility bear a current market rate of interest. Our approximately $39.5 million of outstanding 9-1/8% Senior Notes, due 2006, have a fixed interest rate. Our approximately $170.5 million principal of 11¾% Senior Notes outstanding, due 2009, also have a fixed interest rate. Accordingly, our long-term debt is not exposed to cash flow risk from interest rate changes; however, our long-term debt is exposed to fair value risk. The estimated fair value of the 9-1/8% Senior Notes at March 31, 2003 was $40.3 million and the estimated fair value of the 11¾% Senior Notes was $184.1 million.
ITEM 4. CONTROLS AND PROCEDURES
We maintain a set of disclosure controls and procedures that are designed to ensure that information required to be disclosed by us in the reports filed by us under the Securities Exchange Act of 1934, as amended (“Exchange Act”) is recorded, processed, summarized and reported within the time periods specified in the SEC’s rules and forms. Within the 90 days prior to the date of this report, we carried out an evaluation, under the supervision and with the participation of our management, including our Chairman of the Board, President and Chief Executive Officer and our Executive Vice President - Finance & Administration, Chief Financial Officer of the effectiveness of our disclosure controls and procedures pursuant to Rule 13a-14 of the Exchange Act. Based on that evaluation, our Chairman of the Board, President and Chief Executive Officer and our Executive Vice President - Finance & Administration, Chief Financial Officer, concluded that our disclosure controls and procedures are effective.
There have been no significant changes in our internal controls or other factors that could significantly affect those controls subsequent to the date of their evaluation, including any corrective actions with regard to significant deficiencies and material weaknesses.
| ITEM 1. | Legal Proceedings - None, that in the opinion of management, would have a material impact on the registrant. |
| ITEM 2. | Changes in Securities - There have been no changes in the constituent instruments defining the rights of the holders of any class of registered securities during the current quarter. |
| ITEM 3. | Defaults Upon Senior Securities - None. |
| ITEM 4. | Submission of Matters to a Vote of Security Holders - The annual meeting of the registrant was held April 17, 2003 with the shareholders approving the proposals for the election of seven directors and the appointment of Deloitte & Touche LLP as the Company’s auditors. |
| ITEM 5. | Other Information - None. |
| ITEM 6. | Exhibits and Reports on Form 8-K - (a) Exhibits 2.1 – Agreement and Plan of Merger dated March 30, 2003, by and among Frontier Oil Corporation, Front Range Himalaya Corporation, Front Range Merger Corporation, Himalaya Merger Corporation and Holly Corporation (incorporated by reference and filed as Exhibit 99.2 to Form 8-K dated March 30, 2003, filed April 2, 2002, File Number 001-07627). 31.1 – Certification by Chief Executive Officer pursuant to Rule 13a-14(a) and 15d-14(a) under the Exchange Act 31.2 – Certification by Chief Financial Officer pursuant to Rule 13a-14(a) and 15d-14(a) under the Exchange Act 32.1 – Certification by Chief Executive Officer pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002. 32.2 – Certification by Chief Financial Officer pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002. (b) Reports on Form 8-K A report on Form 8-K dated March 30, 2003 was filed April 2, 2003, File Number 001-07627. This report included Item 5 for the reporting of Other Events and Item 7(c) – Exhibits and provided information on the Agreement and Plan of Merger between Frontier Oil Corporation and Holly Corporation, Exhibits included the Agreement and Plan of Merger and related supporting agreements including Holly Holder Support Agreement, Frontier Affiliate’s Support Agreement and Registration Rights Agreement. A report on Form 8-K was dated and filed April 2, 2003, File Number 001-07627. This report included Item 5 for the reporting of Other Events and Item 7(c) – Exhibits and announced that Frontier Oil Corporation was proposing to make a private placement of senior notes. A report on Form 8-K dated May 1, 2003 was filed May 2, 2003, File Number 001-07627. This report included Item 7 for the reporting of Financial Statements and Item 9 Regulation FD Disclosure and included the press release with financial results for Frontier Oil Corporation for the quarter ended March 31, 2003. A report on Form 8-K dated April 17, 2003 was filed May 9, 2003, File Number 001-07627. This report included Item 5 for the reporting of Other Events and Item 7(c) – Exhibits, which included the Registration Rights Agreement dated March 30, 2003, as amended, among Frontier Oil Corporation and other parties, executed in connection with the Agreement and Plan of Merger between Frontier Oil Corporation and Holly Corporation. The Registration Rights Agreement was previously filed as Exhibit 99.5 to Frontier’s current report on Form 8-K dated March 30, 2003 and filed April 2, 2003. A report on Form 8-K dated May 12, 2003 was filed May 14, 2003, File Number 001-07627. This report included as exhibits an amendment dated May 12, 2003 to the Agreement and Plan of Merger between Frontier Oil Corporation and Holly Corporation (previously filed as an exhibit to Form 8-K dated March 30, 2003 and filed April 2, 2003) and the Contingent Value Rights Agreement dated May 12, 2003 executed in connection with the Agreement and Plan of Merger. |
SIGNATURES
Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.
| FRONTIER OIL CORPORATION |
| By: | /s/ Nancy J. Zupan –––––––––––––––––––– Nancy J. Zupan Vice President - Controller (principal accounting officer) |
Date: October 31, 2003