Table of Contents

 
 
UNITED STATES SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
 
Form 10-Q
     
þ   QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
FOR THE QUARTERLY PERIOD ENDED SEPTEMBER 30, 2006
OR
     
o   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: 001-32567
 
Alon USA Energy, Inc.
(Exact name of Registrant as specified in its charter)
 
     
Delaware
(State or other jurisdiction of
incorporation or organization)
  74-2966572
(I.R.S. Employer
Identification No.)
7616 LBJ Freeway, Suite 300, Dallas, Texas 75251
(Address of principal executive offices) (Zip Code)
(972) 367-3600
(Registrant’s telephone number, including area code)
 
     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 þ No o
     Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer or a non-accelerated filer. See definition of “accelerated filer and large accelerated filer” in Rule 12b-2 of the Exchange Act. (Check one):
Large Accelerated Filer o   Accelerated Filer o   Non-Accelerated Filer þ
     Indicate by check whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). Yes o No þ
     The number of shares of the Registrant’s common stock, par value $0.01 per share, outstanding as of November 10, 2006 was 46,806,443.
 
 

 


 

         
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 First Amendment to Stock Purchase Agreement
 Second Amendment to Stock Purchase Agreement
 Certification of CEO Pursuant to Section 302
 Certification of CFO Pursuant to Section 302
 Certification of CEO & CFO Pursuant to Section 906

 


Table of Contents

PART I. FINANCIAL INFORMATION
ITEM 1. FINANCIAL STATEMENTS
ALON USA ENERGY, INC. AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
(dollars in thousands except per share data)
                 
    September 30,     December 31,  
    2006     2005  
    (Unaudited)          
ASSETS
               
Current assets:
               
Cash and cash equivalents
  $ 43,913     $ 136,820  
Short-term investments
          185,320  
Accounts and other receivables, net
    243,834       89,529  
Inventories
    276,772       79,181  
Prepaid expenses and other current assets
    13,305       6,264  
 
           
Total current assets
    577,824       497,114  
 
           
Investment in subsidiaries
    38,869       22,754  
Property, plant and equipment, net
    762,677       211,410  
Other assets
    96,358       27,502  
 
           
Total assets
  $ 1,475,728     $ 758,780  
 
           
 
               
LIABILITIES AND STOCKHOLDERS’ EQUITY
               
Current liabilities:
               
Accounts payable
  $ 250,069     $ 157,076  
Accrued liabilities
    56,254       48,128  
Current portion of deferred gain on disposition of assets
    10,400       11,427  
Current portion of long-term debt
    14,929       4,487  
 
           
Total current liabilities
    331,652       221,118  
 
           
Other non-current liabilities
    50,110       18,345  
Deferred gain on disposition of assets
    45,061       52,433  
Long-term debt
    494,364       127,903  
Deferred income tax liability
    270,789       52,422  
 
           
Total liabilities
    1,191,976       472,221  
 
           
Commitments and contingencies (note 15)
               
Minority interest in subsidiaries
    8,428       7,066  
 
           
Stockholders’ equity:
               
Preferred stock, par value $0.01, 10,000,000 shares authorized; no shares issued and outstanding
           
Common stock, par value $0.01, 100,000,000 shares authorized; 46,806,443 and 46,809,857 shares issued and outstanding at September 30, 2006 and December 31, 2005, respectively
    468       468  
Additional paid-in capital
    181,494       181,108  
Accumulated other comprehensive loss, net of income tax
    (2,596 )     (2,596 )
Retained earnings
    95,958       100,513  
 
           
Total stockholders’ equity
    275,324       279,493  
 
           
Total liabilities and stockholders’ equity
  $ 1,475,728     $ 758,780  
 
           
The accompanying footnotes are an integral part of these financial statements.

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ALON USA ENERGY, INC. AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF OPERATIONS
(unaudited, dollars in thousands except earnings and cash dividends per share)
                                 
    For the Three Months Ended     For the Nine Months Ended  
    September 30,     September 30,  
    2006     2005     2006     2005  
Net sales
  $ 1,020,887     $ 648,135     $ 2,277,850     $ 1,646,475  
Operating costs and expenses:
                               
Cost of sales
    881,998       565,820       1,936,514       1,415,421  
Direct operating expenses
    35,579       24,550       81,014       63,259  
Selling, general and administrative expenses
    24,298       16,083       62,105       51,731  
Depreciation and amortization
    9,551       5,470       20,482       15,322  
 
                       
Total operating costs and expenses
    951,426       611,923       2,100,115       1,545,733  
 
                       
Gain on disposition of assets
    2,304       8,020       59,969       37,243  
 
                       
Operating income
    71,765       44,232       237,704       137,985  
Interest expense
    (9,755 )     (4,827 )     (20,151 )     (14,579 )
Equity earnings in subsidiaries
    1,422       321       2,175       733  
Other income, net
    2,147       1,269       6,248       2,349  
 
                       
Income before income tax expense and minority interest in income of subsidiaries
    65,579       40,995       225,976       126,488  
Income tax expense
    25,219       16,225       83,352       48,234  
 
                       
Income before minority interest in income of subsidiaries
    40,360       24,770       142,624       78,254  
Minority interest in income of subsidiaries
    2,217       382       7,226       3,948  
 
                       
Net income
  $ 38,143     $ 24,388     $ 135,398     $ 74,306  
 
                       
Earnings per share
  $ 0.82     $ 0.57     $ 2.90     $ 1.98  
 
                       
 
                               
Weighted average shares outstanding
    46,736,967       42,821,120       46,733,699       37,607,787  
 
                       
Cash dividends per share
  $ 2.54     $ 1.96     $ 2.99     $ 1.96  
 
                       
The accompanying footnotes are an integral part of these financial statements.

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ALON USA ENERGY, INC. AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CASH FLOWS
(unaudited, dollars in thousands)
                 
    For the Nine Months Ended  
    September 30,  
    2006     2005  
Cash flows from operating activities:
               
Net income
  $ 135,398     $ 74,306  
Adjustments to reconcile net income to cash provided by operating activities:
               
Depreciation and amortization
    20,482       15,322  
Stock compensation
    2,123       1,693  
Deferred income tax expense
    22,658       14,599  
Minority interest in income of subsidiaries
    7,226       3,948  
Equity earnings in subsidiaries (net of dividends)
    (375 )      
Gain on disposition of assets
    (59,969 )     (37,243 )
Changes in operating assets and liabilities, net of acquisition effects:
               
Accounts and other receivables, net
    (48,300 )     (43,355 )
Inventories
    7,576       (18,414 )
Prepaid expenses and other current assets
    12,559       (5,069 )
Other assets
    14,984       2,331  
Accounts payable
    (14,042 )     35,704  
Accrued liabilities
    (21,334 )     (7,889 )
Other non-current liabilities
    9,442       (3,451 )
 
           
Net cash provided by operating activities
    88,428       32,482  
 
           
 
               
Cash flows from investing activities:
               
Capital expenditures
    (27,378 )     (17,568 )
Turnaround and chemical catalyst expenditures
    (2,990 )     (11,371 )
Proceeds from disposition of assets, net
    68,000       118,000  
Acquisition of assets from Good Time Stores
    (27,024 )      
Acquisition of Paramount Petroleum stock
    (504,381 )      
Acquisition of assets from Edgington Oil Company
    (92,976 )      
Sale (purchase) of short-term investments, net
    185,320       (29,675 )
Dividends from investment in HEP (net of equity earnings)
          322  
Minority interest shares purchased
    (186 )     (5,098 )
 
           
Net cash (used in) provided by investing activities
    (401,615 )     54,610  
 
           
 
               
Cash flows from financing activities:
               
Payments received for shares issued, net
          172,287  
Dividends paid to minority interest stockholders
    (7,863 )     (6,134 )
Dividends paid to stockholders
    (139,953 )     (68,479 )
Deferred debt issuance costs
    (8,807 )      
Revolving credit facility, net
    8,134        
Additions to long-term debt
    500,000       2,936  
Payments on long-term debt
    (131,231 )     (57,765 )
 
           
Net cash provided by financing activities
    220,280       42,845  
 
           
 
               
Net change in cash and cash equivalents
    (92,907 )     129,937  
Cash and cash equivalents, beginning of period
    136,820       63,357  
 
           
Cash and cash equivalents, end of period
  $ 43,913     $ 193,294  
 
           
 
               
Supplemental cash flow information:
               
Cash paid for interest
  $ 12,096     $ 13,283  
 
           
Cash paid for income tax
  $ 51,172     $ 21,467  
 
           
 
               
Non-cash activities:
               
Investing activity – receipt of Class B HEP subordinated units as proceeds from disposition of assets
  $     $ 30,000  
 
           
The accompanying footnotes are an integral part of these financial statements.

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ALON USA ENERGY, INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(unaudited, dollars in thousands except as noted)
     (1) Basis of Presentation and Certain Significant Accounting Policies
          (a) Basis of Presentation
          The consolidated financial statements include the accounts of Alon USA Energy, Inc. and its subsidiaries (collectively, “Alon”). All significant intercompany balances and transactions have been eliminated. These consolidated financial statements of Alon are unaudited and have been prepared in accordance with United States generally accepted accounting principles (“GAAP”) for interim financial information and with the instructions to Form 10-Q and Article 10 of Regulation S-X of the Securities Exchange Act of 1934. Accordingly, they do not include all of the information and notes required by GAAP for complete consolidated financial statements. In the opinion of Alon’s management, the information included in these consolidated financial statements reflects all adjustments, consisting of normal and recurring adjustments, which are necessary for a fair presentation of Alon’s consolidated financial position and results of operations for the interim periods presented. The results of operations for the interim periods are not necessarily indicative of the operating results that may be obtained for the year ending December 31, 2006.
          The consolidated balance sheet as of December 31, 2005 has been derived from the audited financial statements as of that date. These unaudited consolidated financial statements should be read in conjunction with the audited consolidated financial statements and notes thereto included in Alon’s Annual Report on Form 10-K for the year ended December 31, 2005.
          (b) Revenue Recognition
          In September 2005, the Emerging Issues Task Force, (“EITF”) reached a consensus concerning the accounting for linked purchase and sale arrangements in EITF Issue No. 04-13, Accounting for Purchases and Sales of Inventory with the Same Counterparty. The EITF concluded that non-monetary exchanges of finished goods inventory within the same line of business be recognized at the carrying value of the inventory transferred. Alon began applying this consensus for new buy/sell arrangements beginning January 1, 2006.
          Alon occasionally enters into refined product buy/sell arrangements, which involve linked purchases and sales related to refined product sales contracts entered into to address location, quality or grade requirements. As of January 1, 2006, these buy/sell transactions are included on a net basis in sales in the consolidated statements of operations and profits are recognized when the exchanged product is sold. Prior to the adoption of EITF Issue No. 04-13, the results of these linked refined product buy/sell transactions were recorded separately in sales and cost of sales in the consolidated statements of operations. In the ordinary course of business, logistical and refinery production schedules necessitate the occasional sale of crude oil to third parties. All purchases and sales of crude oil, currently and historically, are recorded on a net basis, in cost of sales in the consolidated statements of operations.
          Sulfur credits purchased to meet federal gasoline sulfur regulations are recorded in inventory at the lower of cost or market. Cost is computed on an average cost basis. Purchased sulfur credits are removed from inventory and charged to cost of sales in the consolidated statements of operations as they are utilized. Sales of excess sulfur credits are recognized in earnings and included in net sales in the consolidated statements of operations.
          (c) New Accounting Standards
          Effective January 1, 2006, Alon adopted Statement of Financial Accounting Standards No. 123R, Share-Based Payment (“SFAS No. 123R”), which requires use of the fair-value based method and expensing of stock options and other share-based compensation payments to employees, net of estimated forfeitures, over the requisite service period and supersedes SFAS No. 123, which had allowed companies to choose between expensing stock options or showing pro-forma disclosure only. As a private company, Alon used the minimum value method of measuring equity share options for pro-forma disclosure purposes under SFAS No. 123. Accordingly, Alon applied

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ALON USA ENERGY, INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(unaudited, dollars in thousands except as noted)
SFAS No. 123R prospectively to new awards and to awards modified, repurchased or forfeited after January 1, 2006. Alon applied the modified prospective transition method to any unvested stock-based awards issued after its initial public offering (“IPO”). The adoption of SFAS No. 123R did not have a significant effect on Alon’s financial position or results of operations.
          Alon previously accounted for stock-based compensation using the intrinsic value method prescribed in Accounting Principles Board (“APB”) Opinion No. 25, Accounting for Stock Issued to Employees, and related interpretations (“Opinion 25”). Accordingly, compensation cost for stock options was measured as the excess of the estimated fair value of the common stock over the exercise price and was recognized over the scheduled vesting period on an accelerated basis. Stock compensation expense is presented as selling, general and administrative expenses in the accompanying consolidated statements of operations. All pre-IPO stock-based awards will continue to be accounted for under Opinion 25.
          In November 2004, the Financial Accounting Standards Board (“FASB”) issued Statement No. 151, Inventory Costs, which clarifies the accounting for abnormal amounts of idle facility expense, freight, handling costs, and wasted material and requires that those items be recognized as current-period charges. Statement No. 151 also requires that allocation of fixed production overhead to the costs of conversion be based on the normal capacity of the production facilities. Statement No. 151 is effective for fiscal years beginning after June 15, 2005. The adoption of Statement No. 151 did not have a material effect on Alon’s financial position or results of operations.
          In December 2004, the FASB issued FASB Staff Position (“FSP”) FAS 109-1, Application of FASB Statement No. 109, Accounting for Income Taxes, for the Tax Deduction Provided to U.S. Based Manufacturers by the American Jobs Creation Act of 2004 (“Jobs Creation Act”) which requires a company that qualifies for the deduction for domestic production activities under the Jobs Creation Act to account for it as a special deduction under FASB Statement No. 109, Accounting for Income Taxes, as opposed to an adjustment of recorded deferred tax assets and liabilities.
          In June 2006, the FASB issued Interpretation No. 48, Accounting for Uncertainty in Income Taxes, an interpretation of FASB Statement No. 109 (“FIN No. 48”). This interpretation prescribes a “more-likely-than-not” recognition threshold and measurement attribute (the largest amount of benefit that is greater than 50% likely of being realized upon ultimate settlement with tax authorities) for the financial statement recognition and measurement of a tax position taken or expected to be taken in a tax return. This interpretation also provided guidance on derecognition, classification, interest and penalties, accounting in interim periods, disclosure and transition. FIN No. 48 is effective for fiscal years beginning after December 15, 2006. Alon will adopt the provisions of FIN No. 48 on January 1, 2007 and does not expect these provisions to have a material effect on Alon’s results of operations, financial condition or liquidity.
          During September 2006, the FASB issued Statement of Financial Accounting Standards No. 158, Employers’ Accounting for Defined Benefit Pension and Other Postretirement Plans. This statement requires recognition of the funded status of the plans, measured as of the fiscal year end. Alon is required to adopt the recognition provision prospectively as of the end of 2006. Alon currently uses the required measurement date. Adopting this statement will increase the accumulated other comprehensive loss. Alon is currently assessing the impact on the consolidated financial statements. The adoption of this statement as of December 31, 2005, would have increased accumulated other comprehensive loss, net of income tax by approximately $5,000.
          SEC Staff Guidance – Qualifying Financial Statement Misstatements. During September 2006, the SEC Staff issued Staff Bulletin No. 108, which discusses the process of quantifying financial statement misstatements. Alon is not currently aware of any impact Staff Accounting Bulletin No. 108 will have on the consolidated financial statements; however, Alon plans to adopt the interpretation during the fourth quarter of 2006.

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ALON USA ENERGY, INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(unaudited, dollars in thousands except as noted)
     (2) Acquisitions
          Good Time Stores Acquisition
          On July 3, 2006, Alon completed the purchase of 40 retail stores from Good Time Stores in El Paso, Texas. The purchase price for the 40 stores acquired was $27,024 in cash, including $2,349 for inventories and assumption of certain lease obligations. This acquisition gives Alon a leading market share in El Paso and is consistent with Alon’s strategy of strengthening its integrated marketing sector.
          In conjunction with the Good Time Stores acquisition, Alon, through a wholly-owned subsidiary, completed a draw down of $50,000 under a new credit agreement dated June 6, 2006. Of this $50,000, $19,800 was used to finance the acquisition and $30,200 was used to refinance existing retail segment debt.
          The purchase price has been preliminarily allocated as set forth below based on estimated fair values of the assets acquired and the goodwill assumed at the date of acquisition, pending the completion of an independent appraisal and other evaluations.
         
Cash paid
  $ 26,043  
Transaction costs
    981  
 
     
Total Purchase Price
  $ 27,024  
 
     
          As of July 3, 2006 the balance sheet was affected as follows:
         
Inventories
  $ 2,349  
Property, plant and equipment
    5,014  
Intangible assets
    4,000  
Goodwill
    15,661  
 
     
Total Purchase Price
  $ 27,024  
 
     
          Goodwill represents the excess of the purchase price over the fair value of identifiable net assets acquired. Alon’s expected discounted future value of cash flows and additional scale were the primary factors contributing to the recognition of goodwill.
          Paramount Acquisition
          On August 4, 2006, Alon completed the purchase of the stock of Paramount Petroleum Corporation (“Paramount”), an independent refiner of petroleum products. Paramount’s assets include refineries, located in Paramount, California, and Portland, Oregon with a refining capacity of 66,000 barrels of heavy crude oil per day. In addition, Paramount owns petroleum product tank farms and seven asphalt terminals located in Seattle, Washington; Elk Grove and Mojave, California; Phoenix, Fredonia, and Flagstaff, Arizona; and Fernley, Nevada (50% interest) and a 50% interest in Wright Asphalt Products Company, which specializes in patented tire rubber modified asphalt products.
          The final purchase price for Paramount is pending settlement of certain post closing adjustments. The purchase price has been preliminarily allocated based on estimated fair values of the assets acquired and the liabilities assumed at the July 31, 2006 effective date of the acquisition, pending the completion of an independent appraisal and other evaluations and settlement of certain post closing adjustments.
         
Cash paid, less unrestricted cash acquired
  $ 501,056  
Transaction costs
    3,325  
 
     
Total Purchase Price
  $ 504,381  
 
     

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ALON USA ENERGY, INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(unaudited, dollars in thousands except as noted)
          Based on the preliminary allocation, Paramount’s balance sheet as of July 31, 2006 was as follows:
         
Current assets, net of unrestricted cash acquired
  $ 301,537  
Property, plant and equipment
    495,064  
Deferred charges and other assets
    11,203  
Equity investment in subsidiaries
    15,836  
Goodwill
    33,333  
Current liabilities, excluding debt
    (135,817 )
Deferred income tax liability
    (194,138 )
Other liabilities
    (22,637 )
 
     
Total Purchase Price
  $ 504,381  
 
     
          Alon retired all of the Paramount debt at the closing of the acquisition.
          Unaudited Pro Forma Financial Information
          The consolidated statements of operations include the results of the Paramount acquisition commencing on August 1, 2006. The following unaudited pro forma financial information assumes:
  The acquisition of Paramount occurred on January 1, 2005;
 
  $400,000 of term debt was incurred to fund the Paramount acquisition on January 1, 2005 and existing Paramount debt was repaid on this date; and
 
  Depreciation expense was higher beginning January 1, 2005 for the higher estimated asset values as of that date.
          The unaudited pro forma financial information is not necessarily indicative of the results of future operations (in thousands, except per share amounts):
                                 
    Three Months Ended   Nine Months Ended
    September 30,   September 30,
    2006   2005   2006   2005
Net sales
  $ 1,149,819     $ 949,218     $ 3,138,100     $ 2,420,375  
Operating income
    60,853       42,533       247,256       138,134  
Net income
    30,026       19,030       131,422       61,578  
Earnings per share
  $ 0.64     $ 0.44     $ 2.81     $ 1.64  
          Edgington Acquisition
          On September 28, 2006, Alon completed the acquisition of Edgington Oil Company (“Edgington”), a heavy crude oil refining company located in Long Beach, California. The acquisition included Edgington’s topping refinery with a nameplate capacity of approximately 40,000 bpd of crude oil. Total consideration for the acquisition consisted of $92,976 in cash, including $34,405 for the value of certain inventories at closing. The purchase of Edgington has no impact on the third quarter results for Alon.

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ALON USA ENERGY, INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(unaudited, dollars in thousands except as noted)
          The purchase price has been preliminarily allocated as set forth below based on estimated fair values of the assets at the date of acquisition, pending the completion of an independent appraisal and other evaluations.
         
Cash paid
  $ 92,405  
Transaction costs
    571  
 
     
Total Purchase Price
  $ 92,976  
 
     
          The balance sheet as of September 28, 2006 is as follows:
         
Current assets, net of unrestricted cash acquired
  $ 1,000  
Inventories
    34,405  
Property, plant and equipment
    57,571  
 
     
Total Purchase Price
  $ 92,976  
 
     
          The Paramount and Edgington acquisitions are consistent with Alon’s general business strategy of increasing cash flows and earnings through the acquisition of assets or businesses that are logical extensions of its existing assets or businesses. The addition of Paramount and Edgington assets has also increased the geographic diversity of Alon’s Refining and Marketing, and Asphalt segment networks by allowing Alon to expand throughout the Southwest region and up the West Coast of the United States. With the addition of the Paramount and Edgington refineries, Alon believes it has diversified the risks associated with being a single asset refinery. Alon intends to apply its experience of increasing reliability, capacity and yields at its Big Spring refinery to the newly-acquired assets in order to maximize the return on investments. These acquisitions have more than doubled the crude oil processing capacity of Alon from 70,000 barrels per day to approximately 170,000 barrels per day and will allow Alon to process heavy crude oils. The acquisitions will give Alon exposure to the West Coast refining margins.
     (3) Sale of Amdel and White Oil Pipelines
          On March 1, 2006, Alon sold its Amdel and White Oil pipelines, which had been inactive since December 2002, to an affiliate of Sunoco Logistics Partners L.P. (“Sunoco”) for total consideration of approximately $68,000. In conjunction with this transaction, Alon entered into a 10-year pipeline Throughput and Deficiency Agreement with options to extend the agreement by four additional 30-month periods. The Throughput and Deficiency Agreement will allow Alon to maintain its physically integrated system by retaining crude oil transportation rights in the pipelines from the Gulf Coast. Pursuant to the Throughput and Deficiency Agreement, Alon has agreed to ship, starting June 1, 2006, a minimum of 15,000 bpd in the pipelines during the term of the agreement. Alon recognized a $52,500 pre-tax gain on disposition of assets in connection with this transaction in the first quarter of 2006.
     (4) Segment Data
          Following the completion of the Paramount and Edgington acquisitions, Alon commenced reporting its operating results in three operating segments: (i) Refining and Marketing (ii) Asphalt and (iii) Retail. These operating segments adhere to the accounting policies used for Alon’s consolidated financial statements as described in Note 1. All previous periods have been reclassified to consistently present the three operating segments. The reportable operating segments are strategic business units that offer different products and services. The segments are managed separately as each segment requires unique technology, marketing strategies and distinct operational emphasis. Each operating segment’s performance is evaluated primarily based on operating income.
          (a) Refining and Marketing Segment
          The refining and marketing segment includes three sour and heavy crude oil refineries in Big Spring, Texas and Paramount and Long Beach, California, and Alon’s related crude oil and refined products pipeline systems and refined products terminating operations. Alon completed the acquisition of Edgington on September 28, 2006. The purchase of Edgington has no impact on the third quarter results for Alon. Alon’s refineries produce petroleum

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ALON USA ENERGY, INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(unaudited, dollars in thousands except as noted)
products including various grades of gasoline, diesel fuel, jet fuel, petrochemicals, petrochemical feedstocks, asphalt, and other petroleum-based products. In addition, finished products are acquired through exchange agreements and third-party suppliers. Alon primarily markets gasoline and diesel under the FINA brand name, through a network of approximately 1,250 locations. Finished products and blendstocks are also marketed through sales and exchanges with other major oil companies, state and federal governmental entities, unbranded wholesale distributors and various other third parties.
          (b) Asphalt Segment
          Alon’s asphalt segment markets asphalt produced at Alon’s three refineries in the refining and marketing segment and at Alon’s fourth refinery in Portland, Oregon, which is included in the asphalt segment. The Portland, Oregon refinery is an asphalt topping refinery with approximately 70% of its production sold as asphalt products. Asphalt produced by the refining and marketing segment is transferred to the asphalt segment at wholesale market prices. Alon’s asphalt segment markets asphalt through twelve refinery/terminal locations in Big Spring, Texas; Paramount, Long Beach, Elk Grove, Bakersfield; and Mojave, California; Portland, Oregon; Seattle, Washington; Fernley, Nevada; and Phoenix, Flagstaff, and Fredonia, Arizona. Alon produces both paving and roofing grades of asphalt and, depending on the terminal, can manufacture performance graded asphalts, emulsions and cutbacks.
          (c) Retail Segment
          Alon’s retail segment operates 207 owned and leased 7-Eleven branded convenience store sites operating primarily in West Texas and New Mexico. These convenience stores typically offer various grades of gasoline, diesel fuel, general merchandise and food and beverage products to the general public under the 7-Eleven and FINA brand names.
          (d) Corporate
          Operations that are not included in one of the other three segments are included in the category Corporate. These operations consist primarily of corporate headquarter operating and depreciation expenses.
          Segment data of and for the three-month and nine-month period ended September 30, 2006 and 2005 are presented below.
                                         
    Refining and                           Consolidated
Three Months ended September 30, 2006   Marketing   Asphalt   Retail   Corporate   Total
Net sales to external customers
  $ 753,834     $ 162,187     $ 104,866     $     $ 1,020,887  
Intersegment sales/purchases
    51,329       (8,711 )     (42,618 )            
Depreciation and amortization
    6,954       334       1,927       336       9,551  
Operating income (loss)
    66,328       5,097       798       (458 )     71,765  
Total assets
    1,105,564       260,825       96,116       13,223       1,475,728  
Turnaround, chemical catalyst and capital expenditures
    2,208       1,032       953       85       4,278  
                                         
    Refining and                           Consolidated
Three Months ended September 30, 2005   Marketing   Asphalt   Retail   Corporate   Total
Net sales to external customers
  $ 522,013     $ 36,658     $ 89,464     $     $     648,135  
Intersegment sales/purchases
    41,816             (41,816 )            
Depreciation and amortization
    3,850       56       1,087       477       5,470  
Operating income (loss)
    48,681       (6,036 )     2,191       (604 )     44,232  
Total assets
    597,303       22,155       72,188       12,137       703,783  
Turnaround, chemical catalyst and capital expenditures
    740       44       873       42       1,699  

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ALON USA ENERGY, INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(unaudited, dollars in thousands except as noted)
                                         
    Refining and                           Consolidated
Nine Months ended September 30, 2006   Marketing   Asphalt   Retail   Corporate   Total
Net sales to external customers
  $ 1,790,686     $ 222,868     $ 264,296     $     $ 2,277,850  
Intersegment sales/purchases
    121,803       (8,711 )     (113,092 )            
Depreciation and amortization
    14,478       456       4,191       1,357       20,482  
Operating income (loss)
    234,635       2,709       2,061       (1,701 )     237,704  
Total assets
    1,105,564       260,825       96,116       13,223       1,475,728  
Turnaround, chemical catalyst and capital expenditures
    25,680       1,400       3,127       161       30,368  
                                         
    Refining and                           Consolidated
Nine Months ended September 30, 2005   Marketing   Asphalt   Retail   Corporate   Total
Net sales to external customers
  $ 1,319,595     $ 76,336     $ 250,544     $     $ 1,646,475  
Intersegment sales/purchases
    114,307       (43 )     (114,264 )            
Depreciation and amortization
    10,629       77       3,190       1,426       15,322  
Operating income (loss)
    144,829       (8,017 )     2,982       (1,809 )     137,985  
Total assets
    597,303       22,155       72,188       12,137       703,783  
Turnaround, chemical catalyst and capital expenditures
    25,664       170       2,903       202       28,939  
          Operating income for each segment consists of net sales less cost of sales, direct operating expenses, selling, general and administrative expenses, depreciation and amortization and gain on disposition of assets. Sales between segments are transferred at current market prices. Consolidated totals presented are after intersegment eliminations.
          Total assets of each segment consist of property, plant and equipment, net of accumulated depreciation; investment in subsidiaries; inventories; accounts receivables; short-term investments; cash and cash equivalents; and other assets directly associated with the segment’s operations. Corporate assets consist primarily of corporate headquarters information technology and administrative equipment, net of accumulated depreciation.
     (5) Cash, Cash Equivalents and Short-Term Investments
          All highly-liquid instruments with a short-term maturity of three months or less at the time of purchase are considered to be cash equivalents.
          Short-term investments primarily consist of highly-rated auction rate securities (“ARS”). Although ARS may have long-term stated maturities, generally 10 to 30 years, Alon has designated these securities as available-for-sale and has classified them as current assets because it views them as available to support its current operations. ARS may be liquidated at par on the rate reset date, which is in intervals of 7 to 49 days, depending on the terms of the security. These securities are carried at cost, which approximates market value.
          For the nine months ended September 30, 2006, significant transactions affecting Alon’s cash balance included Alon’s January 19, 2006 payment of approximately $100,000 in satisfaction of its outstanding borrowings under the secured term loan agreement (see Note 11), Alon’s sale of its Amdel and White Oil pipelines for total consideration of approximately $68,000 (see Note 3) and acquisitions in total of approximately $154,381, net of $470,000 borrowed (see Note 2). Alon has paid dividends of $147,816 in 2006.
     (6) Derivatives and Hedging Activities
          (a) Fair Value of Financial Instruments
          The carrying amounts of Alon’s cash and cash equivalents, short-term investments, receivables, payables and accrued expenses approximate fair value due to the short-term maturities of these assets and liabilities. The

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ALON USA ENERGY, INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(unaudited, dollars in thousands except as noted)
reported amount of long-term debt approximates fair value. Derivative financial instruments are carried at fair value, which is based on quoted market prices.
     (b) Derivative Financial Instruments
     Alon selectively utilizes commodity derivatives to manage its exposure to commodity price fluctuations and interest rate-related derivative instruments to manage its exposure on its debt instruments. Alon does not enter into derivative instruments for any purpose other than cash flow hedging purposes. Accordingly, Alon does not speculate using derivative instruments. Alon has elected not to designate derivative instruments as cash flow hedges for financial accounting purposes. Therefore, changes in the fair value of the derivative instruments are included in income in the period of the change. There is not a significant credit risk on Alon’s derivative instruments which are transacted through counterparties meeting established collateral and credit criteria.
     Alon occasionally uses crude oil and refined product commodity derivative contracts to reduce financial exposure related to price changes on anticipated transactions. Crude oil and refined product forward contracts are used to facilitate the supply of crude oil to the refineries and the sale of refined products while managing price exposure.
     At September 30, 2006, Alon held net forward contracts for purchases of 25,000 barrels of refined products at an average price of $78.42 per barrel with a total contract fair market value (“FMV”) of $1,901. Alon also held net forward contracts for purchases of 35,600 barrels of asphalt products at an average price of $63.33 per barrel with a FMV of $2,328. During the same period Alon also held net forward contracts of sales of 11,750 barrels of crude oil at an average price of $62.44 per barrel with a FMV of $599. These forward contracts were not designated as hedges for accounting purposes. Accordingly, the contracts were recorded at FMV and an unrealized gain of $148 was recorded as an adjustment to net sales in the consolidated statements of operations for the quarter ended September 30, 2006.
     At September 30, 2005, Alon held net forward contracts for purchases of 85,000 barrels of refined products at an average price of $126.29 per barrel with a total contract FMV of $9,031. These derivatives were not designated as hedges for accounting purposes. Accordingly, the derivatives were recorded at FMV and a net unrealized loss of $1,704 was recorded as an adjustment to net sales in the consolidated statements of operations for the quarter ended September 30, 2005.
     In accordance with SFAS No. 133, Accounting for Derivative Instruments and Hedging Activities, all commodity derivative contracts are recorded at fair value and any changes in fair value between periods are recorded in the consolidated statements of operations.
(7) Inventories
     Inventories for Alon are stated at the lower of cost or market. Cost is determined under the last-in, first-out (“LIFO”) method for crude oil, refined products, asphalt and blendstock inventories. Materials and supplies are stated at average cost. Cost for convenience store fuel inventories is determined under the first-in, first-out method (“FIFO”) and cost for the convenience store merchandise inventories is determined under the retail inventory method at FIFO.

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ALON USA ENERGY, INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(unaudited, dollars in thousands except as noted)
     Carrying value of inventories consisted of the following:
                 
    September 30,     December 31,  
    2006     2005  
Crude oil, refined products, asphalt and blendstocks
  $ 251,185     $ 57,822  
Materials and supplies
    6,232       5,880  
Store merchandise
    15,444       12,977  
Store fuel
    3,911       2,502  
 
           
Total inventories
  $ 276,772     $ 79,181  
 
           
     Market values exceeded LIFO costs by $42,788 and $52,198 at September 30, 2006 and December 31, 2005, respectively.
     In determining the carrying amount of Alon’s inventories as of September 30, 2006, Alon recorded a charge of approximately $10,600 to “cost of sales” resulting from the difference between the fair market value recorded for the inventories acquired in the Paramount acquisition under purchase accounting and the amounts required to be recorded in applying Alon’s LIFO accounting policy.
(8) Property, Plant and Equipment, net
     Property, plant and equipment consisted of the following:
                 
    September 30,     December 31,  
    2006     2005  
Refining facilities
  $ 713,884     $ 171,346  
Pipelines and terminals
    40,000       27,237  
Retail
    72,231       63,486  
Other
    10,674       10,691  
 
           
Property, plant and equipment, gross
    836,789       272,760  
Less accumulated depreciation
    (74,112 )     (61,350 )
 
           
Property, plant and equipment, net
  $ 762,677     $ 211,410  
 
           
     On March 1, 2006, Alon sold its Amdel and White Oil pipelines to an affiliate of Sunoco (see Note 3).
     On July 3, 2006, Alon purchased assets from Good Time Stores. On August 4, 2006, Alon purchased the stock of Paramount Petroleum Corporation. On September 28, 2006, Alon purchased assets from Edgington Oil Company (see Note 2).

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ALON USA ENERGY, INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(unaudited, dollars in thousands except as noted)
(9) Other Assets
     Other assets consisted of the following:
                 
    September 30,     December 31,  
    2006     2005  
Deferred turnaround and chemical catalyst expenditures
  $ 16,706     $ 9,865  
Environmental receivables
    12,476       3,257  
Deferred debt issuance costs
    8,722       6,529  
Goodwill
    48,994        
Intangible assets
    4,000        
Other
    5,460       7,851  
 
           
Total other assets
  $ 96,358     $ 27,502  
 
           
(10) Employee and Postretirement Benefits
     Alon has two defined benefit pension plans covering substantially all of its refining and marketing segment employees, excluding West Coast employees. Alon’s policy is to make contributions annually of not less than the minimum funding requirements under the Employee Retirement Income Security Act of 1974. Alon’s anticipated contributions to its pension plans during 2006 have not changed significantly from amounts previously disclosed in Alon’s consolidated financial statements for the year ended December 31, 2005. For the nine months ended September 30, 2006 and 2005, Alon contributed $1,180 and $1,148, respectively, to its qualified pension plan.
     The components of net periodic benefit cost related to Alon’s benefit plans were as follows for the three and nine months ended September 30, 2006 and 2005.
                                 
    For the Three Months Ended     For the Nine Months Ended  
    September 30,     September 30,  
    2006     2005     2006     2005  
Components of net periodic benefit cost:
                               
Service cost
  $ 478     $ 382     $ 1,434     $ 1,075  
Interest cost
    608       535       1,824       1,492  
Expected return on plan assets
    (592 )     (414 )     (1,778 )     (1,241 )
Amortization of net loss
    82       181       248       513  
 
                       
Net periodic benefit cost
  $ 576     $ 684     $ 1,728     $ 1,839  
 
                       
(11) Long-Term Debt
     (a) Revolving Credit Facility
     On February 15, 2006, Alon entered into an amended revolving credit agreement with its lenders. The total commitment under the facility was increased from $141,600 to $240,000 and is available for, among other things, working capital, acquisitions and general corporate purposes. The initial size of the facility is $160,000 with options to increase the size to $240,000 if crude oil prices increase above certain levels or Alon increases its throughput capacity through its subsidiaries that are parties to this agreement.
     Under this amended facility, the term was extended through January 2010; existing borrowing costs and letter of credit fees were reduced; most covenants were eased; limitations on incurrence of debt, distribution of dividends or investment activities were substantially lessened absent existing or resulting default; and the retail subsidiaries were excluded from the facility. The facility is secured by a first lien on cash, accounts receivables, inventories and related assets. All fixed assets previously securing the facility were released in connection with the

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ALON USA ENERGY, INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(unaudited, dollars in thousands except as noted)
February 2006 amendment, but Alon provided a second lien on its fixed assets, excluding assets held by Paramount, under this facility concurrently with the funding of the Credit Suisse term loan described below.
     Amounts borrowed under the revolving credit facility accrue interest at the Eurodollar rate plus 1.5% per annum.
     No borrowings were outstanding under the revolving credit facility at September 30, 2006 and December 31, 2005. As of September 30, 2006 and December 31, 2005, there were $75,383 and $131,727, respectively, of outstanding letters of credit under the revolving credit facility.
     (b) Debt Repayments
     On January 19, 2006, Alon made a payment of approximately $103,900 in satisfaction of its outstanding borrowings under its secured term loan agreement, including applicable accrued interest and prepayment premiums, with available cash on hand. $100,000 represented a voluntary prepayment of the outstanding principal under the term loan agreement, approximately $3,000 represented a prepayment premium and $900 represented accrued and unpaid interest on the principal balance. The $3,000 prepayment premium and $3,894 of unamortized debt issuance costs are included as interest expense in Alon’s consolidated statements of operations for the nine months ended September 30, 2006.
     On July 3, 2006, Alon made a payment of approximately $30,200 in satisfaction of its outstanding borrowings under retail mortgages and equipment loans, including approximately $600 in prepayment premiums. Additionally, $2,197 of unamortized debt issuance costs are included as interest expense in Alon’s consolidated statements of operations for the three and nine months ended September 30, 2006.
     (c) Wachovia
     On June 6, 2006, Southwest Convenience Stores, LLC, a wholly-owned subsidiary of the Company (“SCS”) entered into a Credit Agreement (the “Wachovia Credit Facility”) by and among SCS, as borrower, and Wachovia Bank. Borrowings under the Wachovia Credit Facility are available in the form of (i) a term loan commitment in an aggregate principal amount of $30,000 maturing on June 30, 2016, and (ii) a revolving credit commitment (available in the form of revolving loans and letters of credit) in an aggregate principal amount of $20,000 maturing on June 30, 2009. Revolving loans may be converted by SCS at any time to a term loan maturing on the tenth anniversary of conversion. At the request of SCS, the revolving credit commitment may be increased by an amount not to exceed $10,000. The aggregate amount of the lenders’ commitments under the entire Wachovia Credit Facility may not exceed $60,000. On July 3, 2006, SCS borrowed $50,000 of which $30,200 was used to refinance existing debt and approximately $19,800 was used to finance the acquisition of Good Time Stores. At September 30, 2006, the outstanding balances were $30,000 in the form of a term loan and $20,000 in the form of a revolving loan.
     Borrowings under the Wachovia Credit Facility bear interest at a Eurodollar rate plus 1.5% per annum. Principal payments of term loan borrowings under this credit facility are being paid in monthly installments based on a 15 year amortization term.
     Obligations under the Wachovia Credit Facility are jointly and severally guaranteed by Alon, Alon’s wholly-owned subsidiaries Alon USA Interests, LLC and all of the subsidiaries of SCS. The obligations under the Wachovia Credit Facility are secured by a pledge of substantially all of the assets of SCS and its subsidiaries, including cash, accounts receivable and inventory.
     The Wachovia Credit Facility includes a financial covenant that requires SCS to maintain a ratio of total consolidated EBITDA less income tax expense in cash to total consolidated scheduled principal payments of indebtedness plus interest expense, as of the end of each fiscal year, of not less than 1.25 to 1.0. Compliance with this covenant is determined in the manner specified in the documentation governing the credit facility. Consolidated EBITDA under the Wachovia Credit Facility represents net income plus depreciation, amortization, taxes, interest expense and minority interest less gain on disposition of assets.

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ALON USA ENERGY, INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(unaudited, dollars in thousands except as noted)
     The Wachovia Credit Facility contains customary restrictive covenants on the activities of SCS and its subsidiaries, such as restrictions on liens, mergers, consolidations, sales of assets, additional indebtedness, different businesses, certain lease obligations, and certain restricted payments.
     (d) Credit Suisse
     On June 22, 2006, Alon entered into a Credit Agreement with Credit Suisse (the “Credit Suisse Credit Facility”) with an aggregate available commitment of $450,000. On August 4, 2006, Alon borrowed $400,000 as a term loan upon consummation of the acquisition of Paramount. On September 28, 2006, Alon borrowed an additional $50,000 as a term loan to finance the acquisition of Edgington. The loans under the Credit Suisse Credit Facility will mature on August 2, 2013. At September 30, 2006, the loan rate was Eurodollar plus 2.25%. Principal payments of 1% per annum are to be paid in quarterly installments beginning September 30, 2006. At September 30, 2006, the outstanding balance was $450,000.
     The borrowings under the Credit Suisse Credit Facility bear interest at the range of Eurodollar rate plus 2.50% to the Eurodollar rate plus 1.75% per annum based upon the ratings of the loans by Standard & Poor’s Rating Service and Moody’s Investors Service, Inc. The Credit Suisse Credit Facility is jointly and severally guaranteed by all of Alon’s subsidiaries except for Alon’s retail subsidiaries. The Credit Suisse Credit Facility is secured by a second lien on Alon’s cash, accounts receivable and inventory and a first lien on most of the remaining assets of Alon and its subsidiaries.
     Alon may, from time to time, request an additional $100,000 of term loans under the Credit Suisse Credit Facility provided that the sum of the incremental loans and the then outstanding loans under the Credit Suisse Credit Facility does not exceed $550,000.
     Alon may prepay at any time a portion or all of the outstanding loan balance under the Credit Suisse Credit Facility with no prepayment premium.
     The Credit Suisse Credit Facility contains restrictive covenants, such as restrictions on liens, mergers, consolidations, sales of assets, additional indebtedness, different businesses, certain lease obligations, and certain restricted payments. This facility does not contain any financial maintenance covenants.
     (e) Revolving Credit Facility — Paramount
     Paramount has a Revolving Credit Agreement (the “Paramount Credit Facility”) with a group of financial institutions, which is secured by the assets of Paramount. The Paramount Credit Facility expires on January 15, 2007. On July 26, 2005, the Paramount Credit Facility was amended and restated to increase the available borrowings up to $190,000, and was further amended and restated on June 22, 2006 to increase the available borrowings up to $215,000, consisting of revolving loans and letters of credit. Amounts borrowed under the Paramount Credit Facility accrue interest at the Eurodollar plus 2.5%. The borrowings outstanding under the Paramount Credit Facility at September 30, 2006 were $8,134 and outstanding letters of credit were $125,748.
     Paramount is required to comply with certain restrictive covenants related to working capital and operations under the Paramount Credit Facility as well as financial covenants relating to the current ratio, tangible net worth and a debt service coverage ratio.
(12) Stock Based Compensation
     Alon has two employee incentive compensation plans, (i) the 2005 Incentive Compensation Plan and (ii) the 2000 Incentive Stock Compensation Plan.

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ALON USA ENERGY, INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(unaudited, dollars in thousands except as noted)
     (a) 2005 Incentive Compensation Plan (share value in dollars)
     The 2005 Incentive Compensation Plan is a component of Alon’s overall executive incentive compensation program. The 2005 Incentive Compensation Plan permits the granting of awards in the form of options to purchase common stock, stock appreciation rights, restricted shares of common stock, restricted common stock units, performance shares, performance units and senior executive plan bonuses to Alon’s directors, officers and key employees. Other than the restricted stock grants discussed below, there have been no other awards granted under the 2005 Incentive Compensation Plan.
     In August 2005, Alon granted awards of 10,791 shares of restricted stock and in November 2005 Alon granted an award of 12,500 shares of restricted stock, in each case to certain directors, officers and key employees in connection with Alon’s IPO in July 2005. The participants were allowed to acquire shares at a discounted price of $12.00 per share with a grant date fair value of $16.00 per share for the August 2005 awards and $20.42 per share for the November 2005 award. In November 2005, Alon granted awards of 52,672 shares of restricted stock to certain officers and key employees with a grant date fair value of $20.42 per share. Non-employee directors are awarded an annual grant of Alon’s common stock valued at $25. In August 2005, 2,774 shares of restricted stock were awarded to Alon’s non-employee directors with a grant date fair value of $18.03 per share. In May 2006, 2,253 shares of restricted stock were awarded to non-employee directors with a grant date fair value of $33.29 per share. Additionally, restricted shares of 5,667 were forfeited and 2,833 shares were accelerated to vest from the November 2005 issuance. All restricted shares granted under the Incentive Compensation Plan vest over a period of three years, assuming continued service at vesting.
     Compensation expense for the restricted stock grants amounted to $386 for the nine months ended September 30, 2006. There is no material difference between intrinsic value under Opinion 25 and fair value under SFAS No. 123R for pro forma disclosure purposes.
                 
            Weighted Average  
Nonvested Shares   Shares     Grant Date Fair Values  
Nonvested at January 1, 2006
    78,737     $ 19.73  
Granted
    2,253       33.29  
Vested
    (2,833 )     20.42  
Forfeited
    (5,667 )     20.42  
 
           
Nonvested at September 30, 2006
    72,490     $ 20.07  
 
           
     As of September 30, 2006, there was $460 of total unrecognized compensation cost related to non-vested share-based compensation arrangements granted under the 2005 Incentive Compensation Plan. That cost is expected to be recognized over a weighted-average period of 2.1 years.
     (b) 2000 Incentive Stock Compensation Plan
     On August 1, 2000, Alon Assets, Inc. (“Alon Assets”) and Alon USA Operating, Inc. (“Alon Operating”), majority owned, fully consolidated subsidiaries of Alon, adopted an Incentive Stock Compensation Plan pursuant to which Alon’s Board of Directors could grant stock options to certain officers and members of executive management. The 2000 Incentive Stock Compensation Plan authorized grants of options to purchase up to 16,154 shares of common stock of Alon Assets and 6,066 shares of common stock of Alon Operating. All authorized options were granted in 2000 and there have been no additional options granted under this plan. All stock options have ten-year terms. The options are subject to accelerated vesting and become fully exercisable if Alon achieves certain financial performance and debt service criteria. Upon exercise, Alon will reimburse the option holder for the exercise price of the shares and under certain circumstances the related federal and state taxes payable as a result of such exercises (gross-up liability). This plan was closed to new participants subsequent to August 1, 2000, the initial grant date. Total compensation expense recognized under this plan was $1,778 and $1,531 for the nine months ended September 30, 2006 and 2005, respectively.

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ALON USA ENERGY, INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(unaudited, dollars in thousands except as noted)
     The following table summarizes the stock option activity for Alon Assets and Alon Operating for the nine months ended September 30, 2006 and for the years ended December 31, 2005 and 2004 (weighted average exercise price in dollars):
                                 
    Alon Assets     Alon Operating  
            Weighted             Weighted  
    Number of     Average     Number of     Average  
    Options     Exercise     Options     Exercise  
    Outstanding     Price     Outstanding     Price  
Outstanding at January 1, 2004
    12,217     $ 100       4,587     $ 100  
Granted
                       
Exercised
    (1,212 )     100       (455 )     100  
Forfeited and expired
    (1,733 )     100       (650 )     100  
 
                       
Outstanding at December 31, 2004
    9,272       100       3,482       100  
Granted
                       
Exercised
    (1,212 )     100       (455 )     100  
 
                       
Outstanding at December 31, 2005
    8,060       100       3,027       100  
Granted
                       
Exercised
    (1,212 )     100       (455 )     100  
 
                       
Outstanding at September 30, 2006
    6,848     $ 100       2,572     $ 100  
 
                       
(13) Stockholders’ Equity (per share in dollars)
     Common Stock Dividends
     On March 21, 2006, Alon paid a regular quarterly cash dividend of $0.04 per share and a special cash dividend of $0.37 per share on Alon’s common stock to stockholders of record at the close of business on March 1, 2006. In connection with Alon’s cash dividend payment to stockholders on March 21, 2006, the minority interest owners of Alon Assets and Alon Operating received an aggregate cash dividend of approximately $1,078. On June 14, 2006, Alon paid a regular quarterly cash dividend of $0.04 per share on Alon’s common stock to stockholders of record at the close of business on June 1, 2006. In connection with Alon’s cash dividend payment to stockholders on June 14, 2006, the minority interest owners of Alon Assets and Alon Operating received an aggregate cash dividend of approximately $105. On September 14, 2006, Alon paid a regular quarterly cash dividend of $0.04 per share and a special cash dividend of $2.50 per share on Alon’s common stock to stockholders of record at the close of business on September 1, 2006. In connection with Alon’s cash dividend payment to stockholders on September 14, 2006, the minority interest owners of Alon Assets and Alon Operating received an aggregate cash dividend of approximately $6,680.
(14) Earnings Per Share (earnings per share in dollars)
     Basic earnings per share are calculated as net income divided by the average number of shares of common stock outstanding. Diluted earnings per share include the dilutive effect of restricted shares using the treasury stock method.
                                 
    Three Months Ended     Nine Months Ended  
    September 30,     September 30,  
    2006     2005     2006     2005  
Net income
  $ 38,143     $ 24,388     $ 135,398     $ 74,306  
Average number of shares of common stock outstanding
    46,737       42,821       46,734       37,608  
Effect of dilutive restricted shares
    52             42        
 
                       
Average number of shares of common stock outstanding assuming dilution
    46,789       42,821       46,776       37,608  
 
                       
Earnings per share – basic
  $ 0.82     $ 0.57     $ 2.90     $ 1.98  
 
                       
Earnings per share – diluted
  $ 0.82     $ 0.57     $ 2.89     $ 1.98  
 
                       

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ALON USA ENERGY, INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(unaudited, dollars in thousands except as noted)
(15) Commitments and Contingencies
     (a) Other Commitments
     In the normal course of business, Alon has long-term commitments to purchase services such as natural gas, electricity and water for use by its refineries, terminals, pipelines and retail locations. Alon is also party to various refined product and crude oil supply and exchange agreements. These agreements are short-term in nature or provide terms for cancellation.
     (b) Other Contingencies
     Alon is involved in various other claims and legal actions arising in the ordinary course of business. Alon believes the ultimate disposition of these matters will not have a material adverse effect on Alon’s financial position, results of operations or liquidity.
     (c) Environmental
     Alon is subject to loss contingencies pursuant to federal, state, and local environmental laws and regulations. These laws and regulations regulate the discharge of materials into the environment and may require Alon to incur future obligations (i) to investigate the effects of the release or disposal of certain petroleum, chemical, and mineral substances at various sites, (ii) to remediate or restore these sites, (iii) to compensate others for damage to property and natural resources, and (iv) for remediation and restoration costs. These possible obligations relate to sites owned by Alon and associated with past or present operations. Alon is currently participating in environmental investigations, assessments, and cleanups under these regulations at service stations, pipelines and terminals. In the future, Alon may be involved in additional environmental investigations, assessments and cleanups. The magnitude of future costs will depend on factors such as the unknown nature and contamination at many sites, the unknown timing, extent and method of the remedial actions which may be required, and the determination of Alon’s liability in proportion to other responsible parties. Environmental expenditures are expensed or capitalized depending on their future economic benefit. Expenditures that relate to an existing condition caused by past operations and that have no future economic benefit are expensed. Liabilities for expenditures of a non-capital nature are recorded when environmental assessment and/or remediation is probable, and the costs can be reasonably estimated. Substantially all amounts accrued are expected to be paid out over the next five to ten years. The level of future expenditures for environmental remediation obligations is impossible to determine with any degree of reliability.
     Alon had accrued environmental remediation obligations of $33,940 ($1,750 current payable and $32,190 non-current liability) at September 30, 2006 and $4,736 ($1,750 current payable and $2,986 non-current liability) at December 31, 2005. Alon’s environmental liability increased due to the assumption of environmental liabilities in connection with the Paramount acquisition on August 4, 2006. Paramount has indemnification agreements with a prior owner for part of the remediation expenses at its refineries and offsite tank farm, and as a result, has recorded $10,057 as a non-current receivable, which is presented in other assets at September 30, 2006. In connection with the acquisition of the Big Spring refinery, pipeline and terminal assets from Atofina Petrochemicals, Inc. (“FINA”) in August 2000, FINA agreed to indemnify Alon for the costs of environmental investigations, assessments, and clean-ups of known conditions that existed at the acquisition date. Alon has recorded a current receivable of $1,750 and $2,419 as a non-current receivable at September 30, 2006.
(16) Subsequent Event
     On November 7, 2006, Alon declared its regular quarterly cash dividend of $0.04 per share on Alon’s common stock, payable on December 14, 2006 to stockholders of record at the close of business on December 1, 2006.

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ITEM 2.   MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS
     The following discussion of our financial condition and results of operations should be read in conjunction with the audited consolidated financial statements and notes thereto included in Alon’s Annual Report on Form 10-K for the year ended December 31, 2005. In this document, the words “Alon,” “the Company,” “we” and “our” refer to Alon USA Energy, Inc. and its subsidiaries.
FORWARD-LOOKING STATEMENTS
     Certain statements contained in this report and other materials we file with the SEC, or in other written or oral statements made by us, other than statements of historical fact, are “forward-looking statements” as defined in the Private Securities Litigation Reform Act of 1995. Forward-looking statements relate to matters such as our industry, business strategy, goals and expectations concerning our market position, future operations, margins, profitability, capital expenditures, liquidity and capital resources and other financial and operating information. We have used the words “anticipate,” “assume,” “believe,” “budget,” “continue,” “could,” “estimate,” “expect,” “intend,” “may,” “plan,” “potential,” “predict,” “project,” “will,” “future” and similar terms and phrases to identify forward-looking statements.
     Forward-looking statements reflect our current expectations regarding future events, results or outcomes. These expectations may or may not be realized. Some of these expectations may be based upon assumptions or judgments that prove to be incorrect. In addition, our business and operations involve numerous risks and uncertainties, many of which are beyond our control, which could result in our expectations not being realized or otherwise materially affect our financial condition, results of operations and cash flows.
     Actual events, results and outcomes may differ materially from our expectations due to a variety of factors. Although it is not possible to identify all of these factors, they include, among others, the following:
  the synergies and accretion to reported earnings estimated to result from our acquisitions of Paramount Petroleum Corporation (“Paramount”) and Edgington Oil Company (“Edgington”) may not be realized;
  our ability to successfully integrate the operations and employees of Paramount and Edgington and the timing of such integration;
  expected cost savings from the Paramount and Edgington acquisitions may not be fully realized or recognized within the expected time frame, and costs or expenses relating to the acquisitions may be higher than expected;
  revenues or margins following the Paramount and Edgington acquisitions may be lower than expected;
  changes in general economic conditions and capital markets;
  changes in the underlying demand for our products;
  the availability, costs and price volatility of crude oil, other refinery feedstocks and refined products;
  changes in the sweet/sour and light/heavy crude oil spreads;
  actions of customers and competitors;
  changes in fuel and utility costs incurred by our facilities;
  disruptions due to equipment interruption, pipeline disruptions or failure at our or third-party facilities;
  the execution of planned capital projects;
  adverse changes in the credit ratings assigned to our trade credit and debt instruments;

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  the effects of and cost of compliance with current and future state and federal environmental, economic, safety and other laws, policies and regulations;
  operating hazards, natural disasters, casualty losses and other matters beyond our control; and
  the other factors discussed in our annual report on Form 10-K for the year ended December 31, 2005 under the caption “Risk Factors.”
     Any one of these factors or a combination of these factors could materially affect our future results of operations and could influence whether any forward-looking statements ultimately prove to be accurate. Our forward-looking statements are not guarantees of future performance, and actual results and future performance may differ materially from those suggested in any forward looking statements. We do not intend to update these statements unless we are required by the securities laws to do so.
Company Overview
     We are an independent refiner and marketer of petroleum products operating primarily in the Southwestern and Western regions of the United States. We own and operate four sour and heavy crude oil refineries in Texas, California and Oregon, with crude oil throughput capacity of approximately 170,000 barrels per day. Our operating results for the three and nine months ended September 30, 2006 include two months of results for our Paramount, California and Portland, Oregon refineries. The purchase of Edgington has no impact on the third quarter results for Alon. Our business consists of three operating segments: (1) refining and marketing, (2) asphalt and (3) retail.
     Refining and Marketing Segment. Our refining and marketing segment includes three sour and heavy crude oil refineries in Big Spring, Texas; Paramount, California; and Long Beach, California. We refine and market petroleum products, including gasoline, diesel, jet fuel, petrochemicals, petrochemical feedstocks, asphalt and other petroleum products, primarily in the Southwestern, West Coast and South Central regions of the United States. Alon completed the acquisition of Edgington on September 28, 2006. The purchase of Edgington has no impact on the third quarter results for Alon.
     We market refined products produced at our Big Spring refinery in West Texas, Central Texas, Oklahoma, New Mexico and Arizona. We refer to this region as our physically integrated system because we supply our branded and unbranded distributors in this region with refined products produced at our Big Spring refinery and distributed through a network of product pipelines and terminals which we own or access through leases or long-term throughput agreements. We also market refined products in East Texas and Arkansas. We refer to our operations in this region as our non-integrated system because we supply our branded and unbranded distributors in this region with motor fuels obtained from third parties.
     We market gasoline, diesel, jet fuel and other petroleum products produced at our Paramount refinery on an unbranded basis to wholesale distributors, other refiners and other third parties. Our Edgington refinery in Long Beach, California currently does not produce finished gasoline, diesel or jet fuel products and sells unfinished and intermediates to other refineries.
     Asphalt Segment. Our asphalt segment markets asphalt produced at the three refineries in our refining and marketing segment as well as at our fourth refinery in Portland, Oregon, which is included in our asphalt segment. The Portland, Oregon refinery is an asphalt topping refinery with approximately 70 % of its production sold as asphalt products. Asphalt produced at our four refineries is sold by our asphalt segment through twelve refinery/terminal locations in Big Spring, Texas; Paramount, Long Beach, Elk Grove, Bakersfield, and Mojave, California; Portland, Oregon; Seattle, Washington; Fernley, Nevada; and Phoenix, Flagstaff, and Fredonia, Arizona. We market both paving and roofing grades of asphalt and, depending on the terminal, can manufacture performance graded asphalts, emulsions and cutbacks. We work closely with roofing manufacturers and the Department of Transportation in each state we serve to ensure that we produce asphalts that meet or exceed the specifications set out by each state and manufacturer we serve.
     Retail Segment. Our retail segment operates 207 owned and leased 7-Eleven branded convenience store sites operating primarily in West Texas and New Mexico. These convenience stores typically offer various grades

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of gasoline, diesel fuel, general merchandise and food and beverage products to the general public under the 7-Eleven and FINA brand names.
Third Quarter Overview
     Operational Highlights
     Continued favorable differentials between West Texas Intermediate (“WTI”) and West Texas Sour (“WTS”) crude oil and increased production at our Big Spring refinery during the third quarter of 2006 were offset by a decrease in the Gulf Coast 3/2/1 crack spreads. However, despite the decrease in Gulf Coast crack spreads, our Big Spring refinery operating margin increased during the three month period ended September 30, 2006 over the comparable period in 2005. Highlights for the third quarter of 2006 include:
  Our average refinery operating margin for the Big Spring refinery increased by $1.73 per barrel to $14.78 per barrel for the three months ended September 30, 2006, compared to the three months ended September 30, 2005. Our average refinery operating margin increased $3.04 per barrel to $14.93 per barrel for the first nine months of 2006, compared to the first nine months of 2005.
  Refinery production at our Big Spring refinery increased to 68,023 barrels per day (“bpd”) in the third quarter of 2006 compared to 66,747 bpd for the third quarter of 2005. Refinery production at our Big Spring refinery for the nine month period ended September 30, 2006 averaged 64,443 bpd compared to 61,875 bpd for the nine month period ended September 30, 2005.
  The average sweet/sour spread for the three months ended September 30, 2006 was $4.44 per barrel compared to $4.09 per barrel for the three months ended September 30, 2005. The average sweet/sour spread for the first nine months of 2006 was $5.23 per barrel compared to $4.30 per barrel for the first nine months of 2005. The average light/heavy spread for the three months ended September 30, 2006 was $14.80 per barrel compared to $15.46 per barrel for the three months ended September 30, 2005. The average light/heavy spread for the first nine months of 2006 was $15.33 per barrel compared to $15.16 per barrel for the first nine months of 2005.
  Our capital expenditures and turnaround spending for the three months ended September 30, 2006 totaled approximately $4.3 million. Our capital expenditures and turnaround spending for the nine months ended September 30, 2006 totaled approximately $30.4 million, of which approximately $12.0 million related to the ultra low sulfur diesel turnaround and $3.0 million was spent on a chemical catalyst.
  On September 14, 2006, we paid a regular quarterly cash dividend of $0.04 per share and a special cash dividend of $2.50 per share on our common stock to stockholders of record at the close of business on September 1, 2006. In conjunction with our special cash dividend payment to stockholders on September 14, 2006, the minority interest owners of Alon Assets and Alon Operating received an aggregate cash dividend of approximately $6.7 million.
     Retail Convenience Stores Acquisition
     On July 3, 2006, we completed the purchase of 40 retail stores from Good Time Stores in El Paso, Texas. The purchase price for the 40 stores acquired was approximately $27 million in cash, including approximately $2 million for inventories and assumption of certain lease obligations. This acquisition gives Alon a leading market share in El Paso and is consistent with Alon’s strategy of strengthening its integrated marketing sector.
     In conjunction with the Good Time Stores acquisition, Alon, through a wholly-owned subsidiary, Southwest Convenience Stores, LLC (“SCS”), completed a draw down of $50 million under a new credit agreement dated June 6, 2006. Of this $50 million, $19.8 million was used to finance the acquisition and $30.2 million was used to refinance existing retail segment debt.

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     Refinery Acquisitions
     Paramount Acquisition. On August 4, 2006, we completed the purchase of the stock of Paramount , an independent refiner of petroleum products. Paramount’s assets include refineries, located in Paramount, California, and Portland, Oregon with a refining capacity of 66,000 barrels of heavy crude oil per day, seven asphalt terminals located in Seattle, Washington; Elk Grove and Mojave, California; Phoenix, Fredonia and Flagstaff, Arizona; and Fernley, Nevada (50% interest), and a 50% interest in Wright Asphalt Products Company, which specializes in patented tire rubber modified asphalt products. Total consideration for the acquisition consisted of approximately $504 million including the retirement of all of the Paramount debt at closing of approximately $183 million and working capital of approximately $166 million.
     Edgington Acquisition. On September 28, 2006, we completed the acquisition of Edgington, a heavy crude oil refining company located in Long Beach, California. The acquisition included Edgington’s topping refinery with a nameplate capacity of approximately 40,000 bpd of crude oil. Total consideration for the acquisition consisted of approximately $93 million in cash, including approximately $34 million for the value of certain inventories at closing. The purchase of Edgington has no impact on our third quarter results.
Fourth Quarter 2006 Developments
     Crude Pipeline Arrangement
     We have agreed to a 15-year arrangement with Centurion Pipeline L.P. (“Centurion”) pursuant to which Centurion will provide us with pipeline capacity, and we will ship a minimum of 21,500 bpd of crude oil from Midland, Texas to our Big Spring refinery. Crude oil delivery began November 1, 2006.
Major Influences on Results of Operations
     Refining and Marketing
     Refining and Marketing Margins. Our earnings and cash flow from our refining and marketing segment are primarily affected by the difference between refined product prices and the prices for crude oil and other feedstocks. The cost to acquire crude oil and other feedstocks and the price of the refined products we ultimately sell depend on numerous factors beyond our control, including the supply of, and demand for, crude oil, gasoline and other refined products which, in turn, depend on, among other factors, changes in domestic and foreign economies, weather conditions, domestic and foreign political affairs, production levels, the availability of imports, the marketing of competitive fuels and government regulation. While our sales and operating revenues fluctuate significantly with movements in crude oil and refined product prices, it is the spread between crude oil and refined product prices, and not necessarily fluctuations in those prices that affects our earnings.
     3/2/1 Crack Spread. In order to measure our operating performance, we compare our per barrel refinery operating margin to certain industry benchmarks, specifically the Gulf Coast Group III or mid-continent, and West Coast 3/2/1 crack spreads. A 3/2/1 crack spread in a given region is calculated assuming that three barrels of a benchmark crude oil are converted, or cracked, into two barrels of gasoline and one barrel of diesel.
     Sweet/Sour Spread. Our Big Spring refinery is capable of processing substantial volumes of sour crude oil, which has historically cost less than intermediate and sweet crude oils. We measure the cost advantage of refining sour crude oil by calculating the difference between the values of WTI crude oil less the value of WTS crude oil. We refer to this differential as the sweet/sour spread. A widening of the sweet/sour spread can favorably influence our Big Spring refinery’s operating margin.
     Light/Heavy Spread. Our Paramount, Long Beach and Portland refineries are capable of processing substantial volumes of heavy crude oil, which has historically cost less than light crude oils. We measure the cost advantage of refining heavy crude oil by calculating the difference between the values of WTI crude oil less the value of Maya crude oil. We refer to this differential as the light/heavy spread. A widening of the light/heavy spread can favorably influence our West Coast refineries’ operating margins.

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     Operating Costs. The results of operations from our refining and marketing segment are also significantly affected by our refineries’ operating costs, particularly the cost of natural gas used for fuel and the cost of electricity. Natural gas prices have historically been volatile. For example, natural gas prices ranged between $4.20 and $10.63 per MMBTU in the first nine months of 2006. Over the first nine months of 2005, natural gas prices ranged between $5.79 and $14.20 per MMBTU. Typically, electricity prices fluctuate with natural gas prices.
     Seasonality. Demand for gasoline and asphalt products is generally higher during summer months than during winter months due to seasonal increases in highway traffic and road construction work. As a result, the operating results for our refining and marketing and asphalt segments for the first and fourth calendar quarters are generally lower than those for the second and third calendar quarters. The effects of seasonal demand for gasoline and asphalt are partially offset by seasonality in demand for diesel, which in our marketing region is generally higher in winter months as east-west trucking traffic moves south to avoid winter conditions on northern routes.
     Safety and Reliability. Safety, reliability and the environmental performance of our refinery operations are critical to our financial performance. The financial impact of planned downtime, such as a turnaround or major maintenance project, is mitigated through a diligent planning process that considers product availability, margin environment and the availability of resources to perform the required maintenance.
     Inventory. The nature of our business requires us to maintain substantial quantities of crude oil and refined product inventories. Because crude oil and refined products are essentially commodities, we have no control over the changing market value of these inventories. Because our inventory is valued at the lower of cost or market value under the LIFO inventory valuation methodology, price fluctuations generally have little effect on our financial results.
     Retail
     Our earnings and cash flows from our retail segment are primarily affected by the sales and margins of retail merchandise and the sales volumes and margins of motor fuels at our convenience stores. The gross margin of our retail merchandise is equal to retail merchandise sales less the delivered cost of the retail merchandise, net of vendor discounts, measured as a percentage of total retail merchandise sales. Our retail merchandise sales are driven by convenience, branding and competitive pricing. Motor fuel margin is equal to sales less the delivered cost of fuel and motor fuel taxes, measured on cents per gallon, or cpg, basis. Our motor fuel margins are driven by local supply, demand and competitor pricing. Our retail sales are seasonal and peak in the second and third quarters of the year, while the first and fourth quarters usually experience lower overall sales.
Factors Affecting Comparability
     Our financial condition and operating results over the three and nine months ended September 30, 2006 have been influenced by the following factors, which are fundamental to understanding comparisons of our period-to-period financial performance.
     Refinery Acquisitions. The financial information for the three and nine months ended September 30, 2006 includes the results of Paramount for two months of operations. The financial information for the comparable prior periods does not include the operations of Paramount. The purchase of Edgington on September 28, 2006 has no impact on the three and nine months ended September 30, 2006.
     Refinery Turnaround. In the second quarter of 2006, we successfully completed a scheduled turnaround at the Big Spring refinery that enabled the refinery to meet the new ultra low sulfur diesel standard of 15 parts per million (“ppm”) for a total investment of $17.5 million. The average refinery production was reduced during the second quarter of 2006 to 55,720 bpd, while work was completed to meet this new standard. The average refinery production during the second quarter of 2005 was 71,602 bpd.
     Increased Crude Oil Throughput Capacity. In the first quarter of 2005, we successfully completed a major turnaround at our Big Spring refinery. In connection with this turnaround, we expanded our crude oil throughput capacity from 62,000 bpd to 70,000 bpd. The resulting increased production and higher sales volumes should affect the comparability of operating results after the expansion to periods prior to the expansion. Average refinery

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production was 64,443 bpd for the first nine months of 2006 compared to 61,875 bpd for the first nine months of 2005.
     Amdel and White Oil Pipeline Transaction. In connection with the Amdel and White Oil transaction we recognized pre tax gain of $52.5 million in the nine months ended September 30, 2006. Gain on disposition of assets for the nine months ended September 30, 2005 included the $26.7 million initial pre-tax gain and four month’s recognition of deferred gain recorded in connection with the contribution of certain pipeline and terminal assets to HEP.
     Unscheduled Turnaround. In September 2005, we completed a reformer catalyst regeneration that had been previously planned for January 2006. As a result of the downtime associated with the regeneration, refinery throughput for the third quarter 2005 was approximately 66,747 bpd compared to 68,023 bpd for the third quarter of 2006.
     Hurricane Activity. The aftermath of Hurricanes Katrina and Rita in September 2005 resulted in the shutdown of approximately 25% of the refining capacity in the United States which greatly influenced the production and supply of both crude and refined products throughout the country. The average crack spread was extremely strong in the third quarter of 2005 as a result of this interruption. Gulf Coast 3/2/1 crack spreads averaged $17.13 per barrel for the third quarter of 2005 compared to $13.38 per barrel for the third quarter of 2006.
Results of Operations
     Net Sales. Net sales consist primarily of sales of refined petroleum products through our refining and marketing and asphalt segments and sales of merchandise, including food products and motor fuels, through our retail segment. For the refining and marketing segment, net sales consist of gross sales, net of customer rebates, discounts and excise taxes. Net sales for our refining and marketing segment also include intersegment sales to our asphalt and retail segments, which are eliminated through consolidation of our financial statements. Asphalt net sales consist of gross sales, net of discounts and applicable taxes. Retail net sales consist of gross merchandise sales, less rebates, commissions and discounts, and gross fuel sales, including motor fuel taxes. For our petroleum products, net sales are mainly affected by refined product prices and volume changes caused by operations. Our merchandise sales are affected primarily by competition and seasonal influences.
     Cost of Sales. Refining and marketing cost of sales includes crude oil and other raw materials, inclusive of transportation costs. Asphalt cost of sales includes asphalt and asphalt blending materials. Retail cost of sales includes cost of sales for motor fuels and for merchandise. Motor fuel cost of sales represents the net cost of purchased fuel, including transportation costs and associated motor fuel taxes. Merchandise cost of sales includes the delivered cost of merchandise purchases, net of merchandise rebates and commissions.
     Direct Operating Expenses. Direct operating expenses which relate to our refining and marketing and asphalt segments, include costs associated with the actual operations of our refinery, such as energy and utility costs, routine maintenance, labor, insurance and environmental compliance costs. Environmental compliance costs, including monitoring and routine maintenance, are expensed as incurred. All operating costs associated with our crude oil and product pipelines are considered to be transportation costs and are reflected as cost of sales.
     Selling, General and Administrative Expenses. Selling, general and administrative, or SG&A, expenses consist primarily of costs relating to the operations of our convenience stores, including labor, utilities, maintenance and retail corporate overhead costs. Corporate overhead and marketing expenses for our refining and marketing and asphalt segments are also included in SG&A expenses.

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ALON USA ENERGY, INC. AND SUBSIDIARIES CONSOLIDATED
     Summary Financial Tables. The following tables provide summary financial data and selected key operating statistics for Alon and our three operating segments for the three and nine months ended September 30, 2006 and 2005. This date includes results and statistics from Paramount for the two months of August and September 2006. The summary financial data for our three operating segments does not include certain SG&A expenses and depreciation and amortization related to our corporate headquarters. The following data should be read in conjunction with our consolidated financial statements and the notes thereto included elsewhere in this Form 10-Q.
                                 
    For the Three Months Ended     For the Nine Months Ended  
    September 30,     September 30,  
    2006     2005     2006     2005  
    (dollars in thousands, except earnings and  
    cash dividends per share data)  
STATEMENT OF OPERATIONS DATA:
                               
Net sales
  $ 1,020,887     $ 648,135     $ 2,277,850     $ 1,646,475  
Operating costs and expenses:
                               
Cost of sales
    881,998       565,820       1,936,514       1,415,421  
Direct operating expenses
    35,579       24,550       81,014       63,259  
Selling, general and administrative expenses (1)
    24,298       16,083       62,105       51,731  
Depreciation and amortization (2)
    9,551       5,470       20,482       15,322  
 
                       
Total operating costs and expenses
    951,426       611,923       2,100,115       1,545,733  
 
                       
Gain on disposition of assets (3)
    2,304       8,020       59,969       37,243  
 
                       
Operating income
    71,765       44,232       237,704       137,985  
Interest expense (4)
    (9,755 )     (4,827 )     (20,151 )     (14,579 )
Equity earnings in subsidiaries
    1,422       321       2,175       733  
Other income, net
    2,147       1,269       6,248       2,349  
 
                       
Income before income tax expense and minority interest in income of subsidiaries
    65,579       40,995       225,976       126,488  
Income tax expense
    25,219       16,225       83,352       48,234  
 
                       
Income before minority interest in income of subsidiaries
    40,360       24,770       142,624       78,254  
Minority interest in income of subsidiaries
    2,217       382       7,226       3,948  
 
                       
Net income
  $ 38,143     $ 24,388     $ 135,398     $ 74,306  
 
                       
 
                               
Earnings per share (5)
  $ 0.82     $ 0.57     $ 2.90     $ 1.98  
 
                       
 
                               
Weighted average shares outstanding (5)
    46,736,967       42,821,120       46,733,699       37,607,787  
 
                       
Cash dividends per share
  $ 2.54     $ 1.96     $ 2.99     $ 1.96  
 
                       
 
                               
CASH FLOW DATA:
                               
Net cash provided by (used in):
                               
Operating activities
  $ 93,138     $ (16,906 )   $ 88,428     $ 32,482  
Investing activities
    (597,223 )     (33,537 )     (401,615 )     54,610  
Financing activities
    343,650       75,191       220,280       42,845  
 
                               
OTHER DATA:
                               
Adjusted EBITDA (6)
  $ 82,581     $ 43,272     $ 206,640     $ 119,146  
Capital expenditures (7)
    4,213       1,109       27,378       17,568  
Capital expenditures for turnaround and chemical catalyst
    65       590       2,990       11,371  

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    September 30,   December 31,
    2006   2005
BALANCE SHEET DATA (end of period):
               
Cash, cash equivalents and short-term investments
  $ 43,913     $ 322,140  
Working capital
    246,172       275,996  
Total assets
    1,475,728       758,780  
Total debt
    509,293       132,390  
Total stockholders’ equity (8)
    275,324       279,493  
 
(1)   Includes corporate headquarters selling, general and administrative expenses of $122 and $127 for the three months ended September 30, 2006 and 2005, respectively, and $344 and $383 for the nine months ended September 30, 2006 and 2005, respectively, which are not allocated to our three operating segments.
 
(2)   Includes corporate depreciation and amortization of $336 and $477 for the three months ended September 30, 2006 and 2005, respectively, and $1,357 and $1,426 for the nine months ended September 30, 2006 and 2005, respectively, which are not allocated to our three operating segments.
 
(3)   Gain on disposition of assets reported in the nine months ended September 30, 2006, reflects the $52.5 million pre-tax gain on disposition of assets, recorded in connection with the Amdel and White Oil transaction and the recognition of $7.5 million deferred gain recorded in connection with the HEP transaction. Gain on disposition of assets reported in the nine months ended September 30, 2005, reflects the $26.7 million initial pre-tax gain and $10.5 million deferred gain recorded in connection with the HEP transaction. Gain on disposition of assets reported in the third quarter ended September 30, 2006 and 2005, reflects $2.3 million and $8.1 million, respectively, of deferred gain recorded in connection with the HEP transaction.
 
(4)   Interest expense for the nine months ended September 30, 2006, includes $3.0 million prepayment premium and $3.9 million of unamortized debt issuance costs written off as a result of the prepayment of the $100 million term loan in January 2006. Additionally, we prepaid $30.2 million of retail debt in July 2006. This resulted in the write-off of $2.2 million of unamortized debt issuance costs and $0.6 million in prepayment premiums both of which were recorded to interest expense in the third quarter of 2006.
 
(5)   Weighted average common shares outstanding and earnings per common share amounts for the three and nine months ended September 30, 2005 have been restated to reflect the effect of the 33,600-for-one split of our common stock which was effective on July 6, 2005.

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(6)   EBITDA represents earnings before minority interest in income of subsidiaries, income tax expense, interest expense, depreciation and amortization. Adjusted EBITDA represents EBITDA, exclusive of gain on disposition of assets. EBITDA and Adjusted EBITDA are not recognized measurements under GAAP; however, the amounts included in EBITDA and Adjusted EBITDA are derived from amounts included in our consolidated financial statements. Our management believes that the presentation of Adjusted EBITDA is useful to investors because it is frequently used by securities analysts, investors and other interested parties in the evaluation of companies in our industry. In addition, our management believes that Adjusted EBITDA is useful in evaluating our operating performance compared to that of other companies in our industry because the calculation of Adjusted EBITDA generally eliminates the effects of minority interest in income of subsidiaries, income tax expense, interest expense, gain on disposition of assets and the accounting effects of capital expenditures and acquisitions, items which may vary for different companies for reasons unrelated to overall operating performance. EBITDA is the basis for calculating selected financial ratios as required in the debt covenants in our revolving credit agreement. See “—Liquidity and Capital Resources–Cash Position and Indebtedness.”
 
    Adjusted EBITDA has limitations as an analytical tool, and you should not consider it in isolation, or as a substitute for analysis of our results as reported under GAAP. Some of these limitations are:
    Adjusted EBITDA does not reflect our cash expenditures or future requirements for capital expenditures or contractual commitments;
 
    Adjusted EBITDA does not reflect the interest expense or the cash requirements necessary to service interest or principal payments on our debt;
 
    Adjusted EBITDA does not reflect the prior claim that minority stockholders have on the income generated by non-wholly-owned subsidiaries;
 
    Adjusted EBITDA does not reflect changes in or cash requirements for our working capital needs; and
 
    Our calculation of Adjusted EBITDA may differ from the EBITDA calculations of other companies in our industry, limiting its usefulness as a comparative measure.
Because of these limitations, EBITDA and Adjusted EBITDA should not be considered a measure of discretionary cash available to us to invest in the growth of our business. We compensate for these limitations by relying primarily on our GAAP results and using EBITDA and Adjusted EBITDA only supplementally.

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          The following table reconciles net income to Adjusted EBITDA for the three and nine months ended September 30, 2006 and 2005,
          respectively:
                                 
        For the Three Months Ended     For the Nine Months Ended  
        September 30,     September 30,  
        (dollars in thousands)  
        2006     2005     2006     2005  
   
Net income
  $ 38,143     $ 24,388     $ 135,398     $ 74,306  
   
Minority interest in income of subsidiaries
    2,217       382       7,226       3,948  
   
Income tax expense
    25,219       16,225       83,352       48,234  
   
Interest expense
    9,755       4,827       20,151       14,579  
   
Depreciation and amortization
    9,551       5,470       20,482       15,322  
   
 
                       
   
EBITDA
    84,885       51,292       266,609       156,389  
   
Gain on disposition of assets
    (2,304 )     (8,020 )     (59,969 )     (37,243 )
   
 
                       
   
Adjusted EBITDA
  $ 82,581     $ 43,272     $ 206,640     $ 119,146  
   
 
                       
 
(7)   Includes corporate capital expenditures of $85 and $42 for the three months ended September 30, 2006 and 2005, respectively, and $161 and $202 for the nine months ended September 30, 2006 and 2005, respectively, which are not allocated to our other three operating segments.
 
(8)   The stockholders’ equity as of September 30, 2006 includes the effect of dividend distributions of approximately $140 million during the nine months ended September 30, 2006.

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REFINING AND MARKETING SEGMENT
                                 
    For the Three Months Ended     For the Nine Months Ended  
    September 30,     September 30,  
    2006     2005     2006     2005  
    (dollars in thousands, except per barrel data and pricing statistics)  
STATEMENTS OF OPERATIONS DATA:
                               
Net sales (1) (2)
  $ 805,163     $ 563,829     $ 1,912,489     $ 1,433,859  
Operating costs and expenses:
                               
Cost of sales (2)
    702,914       493,398       1,640,141       1,243,050  
Direct operating expenses
    27,074       22,989       69,334       59,392  
Selling, general and administrative expenses
    4,197       2,968       13,870       13,239  
Depreciation and amortization
    6,954       3,850       14,478       10,629  
 
                       
Total operating costs and expenses
  741,139     523,205     1,737,823     1,326,310  
 
                       
Gain on disposition of assets (3)
    2,304       8,057       59,969       37,280  
 
                       
Operating income
  $ 66,328     $ 48,681     $ 234,635     $ 144,829  
 
                       
 
                               
KEY OPERATING STATISTICS:
                               
Total sales volume (bpd)
    112,114       87,313       92,733       84,983  
Non-integrated marketing sales volume (bpd) (4)
    17,651       21,154       18,797       20,590  
Non-integrated marketing margin (per barrel sales volume) (4)
  $ 0.75     $ (4.98 )   $ (0.18 )   $ (1.94 )
Per barrel of throughput:
                               
Refinery operating margin — Big Spring (5)
  $ 14.78     $ 13.05     $ 14.93     $ 11.89  
Refinery operating margin — Paramount (5)
    2.67             2.67        
Refinery direct operating expenses — Big Spring
    2.98       3.75       3.43       3.50  
Refinery direct operating expenses — Paramount
    2.94             2.94        
Capital expenditures
    2,142       150       22,689       14,293  
Capital expenditures for turnaround and chemical catalyst
    66       590       2,991       11,371  
 
                               
PRICING STATISTICS:
                               
WTI crude oil (per barrel)
  $ 70.45     $ 63.03     $ 68.09     $ 55.31  
WTS crude oil (per barrel)
    66.01       58.94       62.86       51.01  
Crack spreads (3/2/1) (per barrel):
                               
Gulf Coast
  $ 13.38     $ 17.13     $ 13.78     $ 11.37  
Group III
    18.30       16.66       15.83       12.12  
West Coast
    24.60       28.56       26.45       23.23  
Crude oil differentials (per barrel):
                               
WTI less WTS
  $ 4.44     $ 4.09     $ 5.23     $ 4.30  
WTI less MAYA
  $ 14.80     $ 15.46     $ 15.33     $ 15.16  
Product price (per gallon):
                               
Gulf Coast unleaded gasoline
    195.2 ¢     192.8 ¢     192.1 ¢     157.9 ¢
Gulf Coast low-sulfur diesel
    208.4       187.0       200.5       160.5  
Group III unleaded gasoline
    205.1       190.7       196.3       159.5  
Group III low-sulfur diesel
    223.7       187.8       206.9       162.6  
West Coast LA Carbob (unleaded gasoline)
    231.5       224.1       230.6       192.5  
West Coast LA ultra low-sulfur diesel
    216.0       206.0       214.2       176.0  
Natural gas (per MMBTU)
  $ 6.18     $ 9.73     $ 6.89     $ 7.75  

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THROUGHPUT AND YIELD DATA: BIG SPRING
                                                                 
    For the Three Months Ended   For the Nine Months Ended
    September 30,   September 30,
    2006   2005   2006   2005
    bpd   %   bpd   %   bpd   %   bpd   %
Refinery crude throughput:
                                                               
Sour crude
    62,961       95.8       55,757       88.4       58,241       95.1       52,862       90.2  
Sweet crude
    2,728       4.2       7,286       11.6       3,033       4.9       5,732       9.8  
 
                                                               
Total crude throughput
    65,689       100.0       63,043       100.0       61,274       100.0       58,594       100.0  
Blendstocks
    3,181               3,669               3,964               3,565          
 
                                                               
Total refinery throughput (6)
    68,870               66,712               65,238               62,159          
 
                                                               
Refinery production (7):
                                                               
Gasoline
    30,347       44.6       29,934       44.8       29,139       45.2       27,643       44.7  
Diesel/jet
    22,775       33.5       22,974       34.4       20,942       32.5       21,386       34.6  
Asphalt
    6,740       9.9       6,976       10.5       6,301       9.8       5,892       9.5  
Petrochemicals
    4,990       7.3       3,975       6.0       4,341       6.7       4,247       6.9  
Other
    3,171       4.7       2,888       4.3       3,720       5.8       2,707       4.4  
 
                                                               
Total refinery production
    68,023       100.0       66,747       100.0       64,443       100.0       61,875       100.0  
 
                                                               
Refinery Utilization (8)
            93.8 %             92.9 %             91.5 %             93.8 %
 
                                                               
THROUGHPUT AND YIELD DATA: PARAMOUNT
                 
    For the Two Months Ended
    September 30,
    2006
    bpd   %
Refinery crude throughput:
               
Sour crude
    23,847       52.0  
Heavy crude
    21,969       48.0  
 
               
Total crude throughput
    45,816       100.0  
Blendstocks
    (231 )        
 
               
Total refinery throughput (6)
    45,585          
 
               
Refinery production (7):
               
Gasoline
    5,677       12.7  
Diesel/jet
    11,182       25.0  
Asphalt
    15,130       33.8  
Other
    12,748       28.5  
 
               
Total refinery production
    44,737       100.0  
 
               
Refinery Utilization (8)
            84.8 %
 
               
 
(1)   Net sales include intersegment sales to our asphalt and retail segments at prices which approximate wholesale market price. These intersegment sales are eliminated through consolidation of our financial statements. Net sales for the nine months ended September 30, 2006 includes $3.3 million for the sale of sulfur credits. Following the acquisition of Paramount and Edgington, we notified the Environmental Protection Agency that we no longer qualify as a “small refiner” which will limit our ability to generate sulfur credits.
 
(2)   Our buy/sell arrangements involve linked purchases and sales related to refined product contracts entered into to address location or grade requirements. As of January 1, 2006, such buy/sell transactions are included on a net basis in sales in the consolidated statements of operations and profits are recognized when the exchanged product is sold. Prior to January 1, 2006, the results of buy/sell transactions were recorded separately in sales and cost of sales in the consolidated statements of operations.

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(3)   Gain on disposition of assets reported in the nine months ended September 30, 2006 reflects the $52.5 million pre-tax gain on disposition of assets, recorded in connection with the Amdel and White Oil transaction and the recognition of $7.5 million deferred gain recorded in connection with the HEP transaction. Gain on disposition of assets reported in the nine months ended September 30, 2005 reflects the $26.7 million initial pre-tax gain and $10.5 million of deferred gain recorded in connection with the HEP transaction.
 
(4)   The non-integrated marketing sales volume represents refined products sales to our wholesale marketing customers located in our non-integrated region. The refined products we sell in this region are obtained from third-party suppliers. The non-integrated marketing margin represents the margin between the net sales and cost of sales attributable to our non-integrated refined products sales volume, expressed on a per barrel basis.
 
(5)   Refinery operating margin for Big Spring is a per barrel measurement calculated by dividing the margin between net sales and cost of sales attributable to our refining and marketing segment, exclusive of net sales and cost of sales relating to our non-integrated system, by our Big Spring refinery’s throughput volumes. Industry-wide refining results are driven and measured by the margins between refined product prices and the prices for crude oil, which are referred to as crack spreads. We compare our refinery operating margins to these crack spreads to assess our operating performance relative to other participants in our industry. The refinery operating margin for Paramount is calculated by dividing the margin between the net sales and cost of sales by the throughput volumes at the Paramount refinery. The refinery operating margin for Paramount includes a non-cash charge of $10.6 million to cost of sales related to the difference between the fair market value of inventories acquired from Paramount and our recorded amounts under LIFO accounting attributable to those inventories. The refinery operating margin for Paramount excluding this non-cash charge would have been $6.48.
 
(6)   Total refinery throughput represents the total barrels per day of crude oil and blendstock inputs in the refinery production process.
 
(7)   Total refinery production represents the barrels per day of various finished products produced from processing crude and other refinery feedstocks through the crude units and other conversion units at the refinery.
 
(8)   Refinery utilization represents average daily crude oil throughput divided by crude oil capacity, excluding planned periods of downtime for maintenance and turnarounds.

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ASPHALT SEGMENT
                                 
    For the Three Months     For the Nine Months  
    Ended September 30,     Ended September 30,  
    2006     2005     2006     2005  
    (dollars in thousands, except per ton data)  
STATEMENTS OF OPERATIONS DATA:
                               
Net sales
  $ 162,187     $ 36,658     $ 222,868     $ 76,336  
Operating costs and expenses
                               
Cost of sales (1)
    143,131       40,955       200,471       79,473  
Direct operating expenses
    8,505       1,561       11,680       3,867  
Selling, general and administrative expenses
    5,120       122       7,552       936  
Depreciation and amortization
    334       56       456       77  
 
                       
Total operating costs and expenses
    157,090       42,694       220,159       84,353  
 
                       
Gain on disposition of assets
                       
 
                       
Operating income (loss)
  $ 5,097     $ (6,036 )   $ 2,709     $ (8,017 )
 
                       
 
                               
KEY OPERATING STATISTICS:
                               
Total sales volume (tons in thousands)
    472       164       693       360  
Price per ton
  $ 343.92     $ 223.62     $ 322.07     $ 239.31  
Asphalt margin per ton
  $ 40.37     $ (26.20 )   $ 32.32     $ (8.71 )
Capital expenditures
  $ 1,032     $ 44     $ 1,400     $ 170  
 
(1)   Cost of sales includes intersegment purchases of asphalt blends from our refining and marketing segment at prices which approximate wholesale market price. These intersegment purchases are eliminated through consolidation of our financial statements.

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RETAIL SEGMENT
                                 
    For the Three Months     For the Nine Months  
    Ended September 30,     Ended September 30,  
    2006     2005     2006     2005  
    (dollars in thousands, except per gallon data)  
STATEMENTS OF OPERATIONS DATA:
                               
Net sales
  $ 104,866     $ 89,464     $ 264,296     $ 250,544  
Operating costs and expenses:
                               
Cost of sales (1)
    87,282       73,283       217,705       207,162  
Selling, general and administrative expenses
    14,859       12,866       40,339       37,173  
Depreciation and amortization
    1,927       1,087       4,191       3,190  
 
                       
Total operating costs and expenses
    104,068       87,236       262,235       247,525  
 
                       
Gain (loss) on disposition of assets
          (37 )           (37 )
 
                       
Operating income
  $ 798     $ 2,191     $ 2,061     $ 2,982  
 
                       
 
                               
KEY OPERATING STATISTICS:
                               
Number of stores (end of period)
    207       167       207       167  
Fuel sales (thousands of gallons)
    21,265       21,706       55,848       69,772  
Fuel sales (thousands of gallons per site per month) (2)
    34       44       34       47  
Fuel margin (cents per gallon) (3)
    15.0 ¢     20.4 ¢     16.3 ¢     14.3 ¢
Fuel sales price (dollars per gallon) (4)
  $ 2.83     $ 2.49     $ 2.67     $ 2.15  
Merchandise sales
  $ 44,692     $ 35,391     $ 115,296     $ 100,246  
Merchandise sales (per site per month) (2)
    72       71       62       67  
Merchandise margin (5)
    32.2 %     33.2 %     32.5 %     33.3 %
Capital expenditures
  $ 953     $ 873     $ 3,127     $ 2,903  
 
(1)   Cost of sales includes intersegment purchases of motor fuels from our refining and marketing segment at prices which approximate wholesale market price. These intersegment purchases are eliminated through consolidation of our financial statements.
 
(2)   Fuel and merchandise sales per site were adjusted to include 167 stores for six months and 207 stores for nine months as a result of the 40 stores purchased on July 3, 2006.
 
(3)   Fuel margin represents the difference between motor fuel sales revenue and the net cost of purchased motor fuel, including transportation costs and associated motor fuel taxes, expressed on a cents per gallon basis. Motor fuel margins are frequently used in the retail industry to measure operating results related to motor fuel sales.
 
(4)   Fuel sales price per gallon represents the average sales price for motor fuels sold through our retail segment.
 
(5)   Merchandise margin represents the difference between merchandise sales revenue and the delivered cost of merchandise purchases, net of rebates and commissions, expressed as a percentage of merchandise sales revenues. Merchandise margins, also referred to as in-store margins, are commonly used in the retail industry to measure in-store, or non-fuel, operating results.

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Three Months Ended September 30, 2006 Compared to the Three Months Ended September 30, 2005
Net Sales
     Consolidated. Net sales for the three months ended September 30, 2006 were $1,020.9 million, compared to $648.1 million for the three months ended September 30, 2005, an increase of $372.8 million or 57.5%. This increase was primarily due to the purchase of Paramount as of July 31, 2006, higher than average refined product prices and increased refinery production over the comparable period in 2005.
     Refining and Marketing Segment. Net sales for our refining and marketing segment were $805.2 million for the three months ended September 30, 2006, compared to $563.8 million for the three months ended September 30, 2005, an increase of $241.4 million or 42.8%. This increase was primarily due to the purchase of Paramount as of July 31, 2006, higher refined product prices, particularly for low-sulfur diesel, and increased production at our Big Spring refinery. While the average price of Gulf Coast unleaded gasoline for the third quarter of 2006 increased 2.4 cents per gallon (“cpg”) to 195.2 cpg, compared to 192.8 cpg in the third quarter of 2005, an increase of 1.2%, the average Gulf Coast low-sulfur diesel price increased by approximately 21.4 cpg to 208.4 cpg in the third quarter of 2006 as compared to 187.0 cpg in the third quarter of 2005, an increase of 11.4%. Our average refinery production in Big Spring increased by 1,276 bpd to 68,023 bpd in the third quarter of 2006, compared to 66,747 bpd during the third quarter of 2005.
     Asphalt Segment. Net sales for our asphalt segment were $162.2 million for the three months ended September 30, 2006, compared to $36.7 million for the three months ended September 30, 2005, an increase of $125.5 million or 342%. This increase was primarily due to the acquisition of Paramount’s seven asphalt terminals effective July 31, 2006. Additionally, the average price per ton of asphalt for the third quarter of 2006 increased $120.3 per ton to $343.92, compared to $223.62 in the third quarter of 2005, an increase of 53.8%.
     Retail Segment. Net sales for our retail segment were $104.9 million for the three months ended September 30, 2006 compared to $89.5 million for the three months ended September 30, 2005, an increase of $15.4 million or 17.2%. This increase was primarily attributable to the acquisition of 40 Good Time stores on July 3, 2006.
Cost of Sales
     Consolidated. Cost of sales was $882.0 million for the three months ended September 30, 2006, compared to $565.8 million for the three months ended September 30, 2005, an increase of $316.2 million or 55.9%. The increase was due to acquisitions and to higher crude oil costs during the third quarter of 2006 as compared to the third quarter of 2005.
     Refining and Marketing Segment. Cost of sales for our refining and marketing segment was $702.9 million for the three months ended September 30, 2006, compared to $493.4 million for the three months ended September 30, 2005, an increase of $209.5 million or 42.5%. This increase was primarily due to the purchase of Paramount as of July 31, 2006, and the increase in crude oil prices during the third quarter of 2006 compared to the third quarter of 2005. The average price per barrel of WTS crude oil for the third quarter of 2006 increased $7.07 per barrel to $66.01 per barrel, compared to $58.94 per barrel for the third quarter of 2005, an increase of 12.0%.
     Asphalt Segment. Cost of sales for our asphalt segment was $143.1 million for the three months ended September 30, 2006, compared to $41.0 million for the three months ended September 30, 2005, an increase of $102.1 million or 249.0%. This increase was primarily due to the acquisition of Paramount’s seven asphalt terminals effective July 31, 2006.
     Retail Segment. Cost of sales for our retail segment was $87.3 million for the three months ended September 30, 2006, compared to $73.3 million for the three months ended September 30, 2005, an increase of $14.0 million or 19.1%. This increase was primarily due to the acquisition of 40 Good Time stores on July 3, 2006.

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Direct Operating Expenses
     Consolidated. Direct operating expenses were $35.6 million for the three months ended September 30, 2006, compared to $24.6 million for the three months ended September 30, 2005, an increase of $11.0 million or 44.7%. This increase was primarily attributable to the acquisition of Paramount effective July 31, 2006.
     Refining and Marketing Segment. Direct operating expenses for our refining and marketing segment for the three months ended September 30, 2006 were $27.1 million, compared to $23.0 million for the three-month period ended September 30, 2005, an increase of $4.1 million or 17.8%. This increase was primarily attributable to the acquisition of Paramount effective July 31, 2006.
     Asphalt Segment. Direct operating expenses for our asphalt segment for the three months ended September 30, 2006 were $8.5 million, compared to $1.6 million for the three months ended September 30, 2005, an increase of $6.9 million or 431.0%. This increase was primarily due to the acquisition of Paramount’s seven asphalt terminals effective July 31, 2006.
Selling, General and Administrative Expenses
     Consolidated. SG&A expenses for the three months ended September 30, 2006 were $24.3 million, compared to $16.1 million for the three months ended September 30, 2005, an increase of $8.2 million or 50.9%. This increase was primarily attributable to approximately $3.0 million for a special employee bonus payment related to special dividend payments on September 14, 2006 and to the purchase of Paramount as of July 31, 2006.
     Refining and Marketing Segment. SG&A expenses for our refining and marketing segment for the three months ended September 30, 2006 were $4.2 million, compared to $3.0 million for the three-month period ended September 30, 2005, an increase of $1.2 million or 40.0%. This increase resulted primarily from higher corporate costs associated with becoming a public company which significantly increased audit expenditures and added costs associated with becoming compliant with the Sarbanes-Oxley Act of 2002. These costs were partially offset by lower selling and advertising expenses.
     Asphalt Segment. SG&A expenses for our asphalt segment for the three months ended September 30, 2006 were $5.1 million, compared to $0.1 million for the three months ended September 30, 2005, an increase of $5.0 million. This increase was primarily due to the acquisition of Paramount’s seven asphalt terminals effective July 31, 2006.
     Retail Segment. SG&A expenses for our retail segment for the three months ended September 30, 2006 were $14.9 million, compared to $12.9 million for the three months ended September 30, 2005, an increase of $2.0 million or 15.5%. This increase was primarily attributable to higher maintenance and credit card costs and the acquisition of 40 Good Time stores on July 3, 2006.
Depreciation and Amortization
     Depreciation and amortization for the three months ended September 30, 2006 was $9.6 million, compared to $5.5 million for the three months ended September 30, 2005. This increase was primarily attributable to the Paramount acquisition and to the completion of the various capital projects in late 2005 and the first nine months of 2006. Partially offsetting this increase was the reduction in depreciation due to the disposition of assets in the HEP and Amdel and White Oil transactions.
Operating Income
     Consolidated. Operating income for the three months ended September 30, 2006 was $71.8 million, compared to $44.2 million operating income for the three months ended September 30, 2005, an increase of $27.6 million or 62.4%. This increase was primarily attributable to higher operating income in our refining and marketing and asphalt segments.

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     Refining and Marketing Segment. Operating income for our refining and marketing segment for the three months ended September 30, 2006 was $66.3 million compared to operating income of $48.7 million for the three months ended September 30, 2005, an increase of $17.6 million or 36.1%. Our Big Spring refinery operating margin for the third quarter of 2006 increased $1.73 per barrel to $14.78 per barrel, compared to $13.05 per barrel in the third quarter of 2005, even though the Gulf Coast 3/2/1 crack spread decreased by 21.9% to an average of $13.38 per barrel in the third quarter of 2006 compared to an average of $17.13 per barrel in the third quarter of 2005. Our refinery operating margins benefited from a widening of the sweet/sour crude oil spread. The average sweet/sour crude oil spread increased to $4.44 per barrel for the third quarter of 2006 compared to the average sweet/sour crude oil spread of $4.09 per barrel for the third quarter of 2005, an increase of 8.6%.
     Asphalt Segment. Operating income for our asphalt segment was $5.1 million for the three months ended September 30, 2006, compared to a loss of $6.0 million for the comparable period in 2005, an increase of $11.1 million. This increase was primarily due to the acquisition of Paramount’s seven asphalt terminals effective July 31, 2006.
     Retail Segment. Operating income for our retail segment was $0.8 million for the three months ended September 30, 2006, compared to $2.2 million for the three months ended September 30, 2005, a decrease of $1.4 million. This decrease was primarily due to the lower fuel sales margins.
Interest Expense
     Interest expense was $9.8 million for the three months ended September 30, 2006, compared to $4.8 million for the three months ended September 30, 2005, an increase of $5.0 million or 104.2%. This increase was primarily attributable to $500 million in new borrowings to finance the acquisitions made during the third quarter of 2006. This resulted in the write-off of $2.2 million of unamortized debt issuance costs and $0.6 million in prepayment premiums both of which were recorded as interest expense in the third quarter of 2006.
Income Tax Expense
     Income tax expense was $25.2 million for the three months ended September 30, 2006, compared to $16.2 million for the three months ended September 30, 2005, an increase of $9.0 million. This increase resulted from our higher taxable income in the third quarter of 2006 compared to the third quarter of 2005. Our effective tax rate was 38.5% for the third quarter of 2006, compared to an effective tax rate of 39.6% for the third quarter of 2005.
Minority Interest In Income Of Subsidiaries
     Minority interest in income of subsidiaries represents the proportional share of net income related to non-voting common stock owned by minority stockholders in two of our subsidiaries, Alon Assets and Alon Operating. Minority interest in income of subsidiaries was $2.2 million for the three months ended September 30, 2006, compared to $0.4 million for the three months ended September 30, 2005, an increase of $1.8 million. This increase was attributable to our increased after-tax income in the quarter as a result of the factors discussed above.
Net Income
     Net income was $38.1 million for the three months ended September 30, 2006, compared to $24.4 million for the three months ended September 30, 2005, an increase of $13.7 million or 56.1%. This increase was attributable to the factors discussed above.
Nine Months Ended September 30, 2006 Compared to the Nine Months Ended September 30, 2005
Net Sales
     Consolidated. Net sales for the nine months ended September 30, 2006 were $2,277.9 million, compared to $1,646.5 million for the nine months ended September 30, 2005, an increase of $631.4 million or 38.3%. This increase was primarily due to the Paramount acquisition, higher than average refined product prices and increased refinery production over the comparable period in 2005.

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     Refining and Marketing Segment. Net sales for our refining and marketing segment were $1,912.5 million for the nine months ended September 30, 2006, compared to $1,433.9 million for the nine months ended September 30, 2005, an increase of $478.6 million or 33.4%. This increase was primarily due to the acquisition of Paramount and to significantly higher refined product prices. The increase in refined product prices that we experienced was similar to the price increases experienced in the Gulf Coast markets. The average price of Gulf Coast unleaded gasoline for the first nine months of 2006 increased 34.2 cpg to 192.1 cpg, compared to 157.9 cpg in the first nine months of 2005, an increase of 21.7%. The average Gulf Coast low-sulfur diesel price increased by approximately 40.0 cpg to 200.5 cpg in the first nine months of 2006 as compared to 160.5 cpg in the first nine months of 2005, an increase of 24.9%.
     Asphalt Segment. Net sales for our asphalt segment were $222.9 million for the nine months ended September 30, 2006, compared to $76.3 million for the nine months ended September 30, 2005, an increase of $146.6 million or 192.1%. This increase was due to the acquisition of Paramount’s seven asphalt terminals effective July 31, 2006.
     Retail Segment. Net sales for our retail segment were $264.3 million for the nine months ended September 30, 2006, compared to $250.5 million for the nine months ended September 30, 2005, an increase of $13.8 million or 5.5%. This increase was primarily attributable to higher fuel sales prices and in-store merchandise sales. Fuel sales volume decreased by 14.0 million gallons, or 20.0%, to 55.8 million gallons for the nine months ended September 30, 2006, compared to 69.8 million gallons for the nine months ended September 30, 2005. Average retail fuel prices were $2.67 per gallon for the first nine months of 2006, compared to average retail fuel prices of $2.15 per gallon for the first nine months of 2005, a 24.2% increase. Merchandise sales increased by $15.1 million, or 15.1%, to $115.3 million for the first nine months of 2006, compared to $100.2 million for the first nine months of 2005.
Cost of Sales
     Consolidated. Cost of sales was $1,936.5 million for the nine months ended September 30, 2006, compared to $1,415.4 million for the nine months ended September 30, 2005, an increase of $521.1 million or 36.8%. This increase was primarily due to the Paramount acquisition and from significantly higher crude oil prices and an increase in refinery production during the first nine months of 2006.
     Refining and Marketing Segment. Cost of sales for our refining and marketing segment was $1,640.1 million for the nine months ended September 30, 2006, compared to $1,243.1 million for the nine months ended September 30, 2005, an increase of $397.0 million or 31.9%. This increase was primarily due to the Paramount acquisition and to higher crude oil prices and an increase in refinery production. The average price per barrel of WTS crude oil for the first nine months of 2006 increased $11.85 per barrel to $62.86 per barrel, compared to $51.01 per barrel for the first nine months of 2005, an increase of 23.2%. Average production for the Big Spring refinery increased to 64,443 bpd, or 4.2%, for the first nine months of 2006, compared to an average production for the Big Spring refinery of 61,875 bpd for the first nine months of 2005.
     Asphalt Segment. Cost of sales for our asphalt segment was $200.5 million for the nine months ended September 30, 2006, compared to $79.5 million for the nine months ended September 30, 2005, an increase of $121.0 million or 152.2%. This increase was primarily due to the acquisition of Paramount’s seven asphalt terminals effective July 31, 2006.
     Retail Segment. Cost of sales for our retail segment was $217.7 million for the nine months ended September 30, 2006, compared to $207.2 million for the nine months ended September 30, 2005, an increase of $10.5 million or 5.1%. This increase was primarily due to higher fuel prices.
Direct Operating Expenses
     Consolidated. Direct operating expenses were $81.0 million for the nine months ended September 30, 2006, compared to $63.3 million for the nine months ended September 30, 2005, an increase of $17.7 million or 28.0%. This increase was primarily attributable to the Paramount acquisition and to higher energy usage as a result

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of higher refinery throughput and maintenance work performed during the low sulfur diesel turnaround in the second quarter of 2006.
     Refining and Marketing Segment. Direct operating expenses for our refining and marketing segment were $69.3 million for the nine months ended September 30, 2006, compared to $59.4 million for the nine months ended September 30, 2005, an increase of $9.9 million or 16.7%. This increase was primarily attributable to the Paramount acquisition and to higher energy usage as a result of higher refinery throughput and maintenance work performed during the low sulfur diesel turnaround in the second quarter of 2006.
     Asphalt Segment. Direct operating expenses for our asphalt segment for the nine months ended September 30, 2006 were $11.7 million, compared to $3.9 million for the nine months ended September 30, 2005, an increase of $7.8 million or 200%. This increase was primarily attributable to the acquisition of Paramount’s seven asphalt terminals effective July 31, 2006.
Selling, General and Administrative Expenses
     Consolidated. SG&A expenses for the nine months ended September 30, 2006 were $62.1 million, compared to $51.7 million for the nine months ended September 30, 2005, an increase of $10.4 million or 20.1%. This increase was primarily due to the Paramount acquisition.
     Refining and Marketing Segment. SG&A expenses for our refining and marketing segment for the nine months ended September 30, 2006 were $13.9 million, compared to $13.2 million for the nine month period ended September 30, 2005, an increase of $0.7 million or 5.3%. This increase resulted from higher corporate costs associated with becoming a public company which significantly increased audit expenditures and added costs associated with becoming compliant with the Sarbanes-Oxley Act of 2002. These costs were partially offset by lower selling and advertising expenses.
     Asphalt Segment. SG&A expenses for our asphalt segment for the nine months ended September 30, 2006 were $7.6 million, compared to $.9 million for the nine months ended September 30, 2005, an increase of $6.7 million or 744.4%. This increase was primarily attributable to the acquisition of Paramount’s seven asphalt terminals effective July 31, 2006.
     Retail Segment. SG&A expenses for our retail segment for the nine months ended September 30, 2006 were $40.3 million, compared to $37.2 million for the nine months ended September 30, 2005, an increase of $3.1 million or 8.3%. This increase was primarily attributable to higher energy costs as a result of the increase in electricity prices, which were partially offset by decreased healthcare and workers compensation costs.
Depreciation and Amortization
     Depreciation and amortization for the nine months ended September 30, 2006 was $20.5 million, compared to $15.3 million for the nine months ended September 30, 2005. This increase was primarily attributable to the completion of the various capital projects in late 2005 and the first nine months of 2006. Partially offsetting this increase was the reduction in depreciation due to the disposition of assets in the HEP and Amdel and White Oil transactions.
Operating Income
     Consolidated. Operating income for the nine months ended September 30, 2006 was $237.7 million, compared to $138.0 million for the nine months ended September 30, 2005. Excluding $52.5 million of net gain on disposition of assets resulting from the Amdel and White Oil transaction and $7.5 million amortization of deferred gain relating to the 2005 HEP transaction, operating income for the nine months ended September 30, 2006 was $177.7 million, compared to $100.7 million operating income (excluding the $37.3 million for gain resulting from the HEP transaction) for the nine months ended September 30, 2005, an increase of $77.0 million or 76.5%. This increase was primarily attributable to higher operating income in our refining and marketing segment.

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     Refining and Marketing Segment. Operating income for our refining and marketing segment for the nine months ended September 30, 2006 was $234.6 million, compared to operating income of $144.8 million for the nine months ended September 30, 2005. Excluding $52.5 million of net gain on disposition of assets resulting from the Amdel and White Oil transaction and $7.5 million amortization of deferred gain relating to the 2005 HEP transaction, operating income for the nine months ended September 30, 2006 was $174.6 million, compared to $107.5 million (excluding the $37.3 million for gain resulting from the HEP transaction) for the nine months ended September 30, 2005, an increase of $67.1 million or 62.4%. This increase was primarily attributable to the increase in our refinery operating margins. Our refinery operating margin for the Big Spring refinery for the first nine months of 2006 increased $3.04 per barrel to $14.93 per barrel, compared to $11.89 per barrel in the first nine months of 2005. This increase was attributable, in part, to higher differentials between refined product prices and crude oil prices resulting from continued concern over adequate refinery capacity to meet demand and supply. Also contributing to the higher refinery margins for the Big Spring refinery were the supply constraints associated with the logistics of the introduction of new reformulated fuels in 2006. The Gulf Coast 3/2/1 crack spread increased by 21.2% to an average of $13.78 per barrel in the first nine months of 2006, compared to an average of $11.37 per barrel in the first nine months of 2005. In addition, our refinery operating margins benefited from a widening of the sweet/sour crude oil spread. The average sweet/sour spread increased $0.93 per barrel to $5.23 per barrel for the first nine months of 2006, compared to the average sweet/sour spread of $4.30 per barrel for the first nine months of 2005, an increase of 21.6%.
     Asphalt Segment. Operating income for our asphalt segment was $2.7 million for the nine months ended September 30, 2006, compared to a loss of $8.0 million for the nine months ended September 30, 2005, an increase of $10.7 million. This increase was primarily attributable to the acquisition of Paramount’s seven asphalt terminals effective July 31, 2006.
     Retail Segment. Operating income for our retail segment was $2.1 million for the nine months ended September 30, 2006, compared to $3.0 million for the nine months ended September 30, 2005, a decrease of $0.9 million. This decrease was primarily attributable to higher fuel costs.
Interest Expense
     Interest expense was $20.2 million for the nine months ended September 30, 2006, compared to $14.6 million for the nine months ended September 30, 2005, an increase of $5.6 million or 38.4%. This increase was primarily attributable to $3.6 million in prepayment premiums and the write-off of $6.1 million of unamortized debt issuance costs resulting from the prepayment of our $100 million term loan in January 2006, and the prepayment of our $30.2 million retail debt in July 2006. Partially offsetting this increase was the reduction of the regular interest expense associated with this term loan and interest from subordinated debt paid off in the third quarter of 2005.
Income Tax Expense
     Income tax expense was $83.4 million for the nine months ended September 30, 2006, compared to $48.2 million for the nine months ended September 30, 2005, an increase of $35.2 million. This increase resulted from our higher taxable income in the nine months ended September 30, 2006, compared to the nine months ended September 30, 2005. Our effective tax rate was 36.9% for the nine months ended September 30, 2006, compared to an effective tax rate of 38.1% for the nine months ended September 30, 2005. This decrease in the effective tax rate is primarily related to expected tax credits associated with the American Jobs Creation Act of 2004.
Minority Interest In Income Of Subsidiaries
     Minority interest in income of subsidiaries represents the proportional share of net income related to non-voting common stock owned by minority stockholders in two of our subsidiaries, Alon Assets and Alon Operating. Minority interest in income of subsidiaries was $7.2 million for the nine months ended September 30, 2006, compared to $3.9 million for the nine months ended September 30, 2005, an increase of $3.3 million. This increase was attributable to our increased after-tax income in the first nine months of 2006 as a result of the factors discussed above.

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Net Income
     Net income was $135.4 million for the nine months ended September 30, 2006, compared to $74.3 million for the nine months ended September 30, 2005, an increase of $61.1 million or 82.2%. This increase was attributable to the factors discussed above.
Liquidity and Capital Resources
     Our primary sources of liquidity are cash on hand, cash generated from our operating activities and borrowings under our revolving credit facility. Significant transactions affecting our liquidity during the nine months ended September 30, 2006 included payment of approximately $100 million in satisfaction of our outstanding borrowings under our term loan, the receipt of $68.0 million net cash proceeds received from the sale of our inactive Amdel and White Oil pipelines, acquisitions of approximately $154.4 million, net of borrowings, and $147.8 million in dividend payments. We believe that our cash on hand, cash flows from operations, borrowings under our revolving credit facilities, and other capital resources will be sufficient to satisfy the anticipated cash requirements associated with our existing operations during the next 12 months. Our ability to generate sufficient cash from our operating activities depends on our future performance, which is subject to general economic, political, financial, competitive and other factors beyond our control. In addition, our future capital expenditures and other cash requirements could be higher than we currently expect as a result of various factors, including any expansion of our business or acquisitions that we complete.
     Depending upon conditions in the capital markets and other factors, we will from time to time consider the issuance of debt or equity securities, or other possible capital market transactions, the proceeds of which could be used to refinance current indebtedness or for other corporate purposes. Pursuant to our growth strategy, we will also consider from time to time additional acquisitions of, and investments in, assets or businesses that complement our existing assets and businesses. Acquisition transactions, if any, are expected to be financed through cash on hand and from operations, bank borrowings, the issuance of debt or equity securities or a combination of two or more of those sources.
Cash Flows
     The following table sets forth our consolidated cash flows for the three and nine months ended September 30, 2006 and 2005:
                                 
    For the Three Months Ended     For the Nine Months Ended  
    September 30,     September 30,  
    2006     2005     2006     2005  
    (dollars in thousands)     (dollars in thousands)  
Cash provided by (used in):
                               
Operating activities
  $ 93,138     $ (16,906 )   $ 88,428     $ 32,482  
Investing activities
    (597,223 )     (33,537 )     (401,615 )     54,610  
Financing activities
    343,650       75,191       220,280       42,845  
 
                       
Net (decrease) increase in cash and cash equivalents
  $ (160,435 )   $ 24,748     $ (92,907 )   $ 129,937  
 
                       
Cash Flows Provided by (Used In) Operating Activities
     Net cash provided by operating activities during the nine months ended September 30, 2006 was $88.4 million, compared to $32.5 million during the nine months ended September 30, 2005. The net change in cash provided by operating activities was primarily attributable to higher net income and partially offset by an increase in accounts receivables as a result of higher fuel prices.
     Net cash provided by operating activities during the three months ended September 30, 2006 was $93.1 million, compared to net cash used in operating activities of $16.9 million during the three months ended September 30, 2005. The net increase in cash provided by operating activities was primarily attributable to a decrease in inventories.

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Cash Flows (Used In) Provided By Investing Activities
     Net cash used in investing activities was $401.6 million during the nine months ended September 30, 2006, compared to cash provided by investing activities of $54.6 million during the nine months ended September 30, 2005. This change was primarily attributable to acquisitions of $624.4 million less the $68.0 million in net proceeds received in the Amdel and White Oil transaction and net sales of short-term investments of $185.3 million. Capital expenditures in the first nine months of 2006 totaled $30.4 million and included $13.5 million for regulatory and compliance projects, $3.0 million for chemical catalyst and $13.9 million for various sustaining and capital improvement projects.
     Net cash used in investing activities was $597.2 million during the three months ended September 30, 2006, compared to $33.5 million for the three months ended September 30, 2005. This increase in cash used in investing activities was attributable to acquisitions of $624.4 million. Capital expenditures for the third quarter of 2006 totaled $4.3 million and included $0.7 million for regulatory and compliance projects, $0.1 million for turnaround and chemical catalyst costs and $3.5 million for various sustaining and capital improvement projects.
Cash Flows Provided By Financing Activities
     Net cash provided by financing activities was $220.3 million during the nine months ended September 30, 2006, compared to $42.8 million during the nine months ended September 30, 2005. Cash provided by financing activities in the first nine months of 2006 included $500 million in new borrowings less the prepayment of our $131.2 million term loans and $147.8 million of dividends paid to stockholders and minority interest stockholders.
     Net cash provided by financing activities was $343.7 million for the three months ended September 30, 2006, compared to $75.2 million during the three months ended September 30, 2005. The cash provided by financing activities in the third quarter of 2006 included $500 million in new borrowings less the prepayment of our $31.2 million term loans and dividends paid to stockholders and minority interest stockholders of $125.7 million.
Cash Position and Indebtedness
     We consider all highly liquid instruments with a maturity of three months or less at the time of purchase to be cash equivalents. Cash equivalents are stated at cost, which approximates market value, and are invested in conservative, highly rated instruments issued by financial institutions or government entities with strong credit standings. Short-term investments primarily consist of highly-rated auction rate securities, or ARS. Although ARS may have long-term stated maturities, generally 10 to 30 years, we have designated these securities as available-for-sale and have classified them as current assets because we view them as available to support our current operations. ARS may be liquidated at par on the rate reset date, which is in intervals of seven to 49 days, depending on the terms of the security. These securities are carried at cost, which approximates market value. As of September 30, 2006, our total cash and cash equivalents were $43.9 million, and we had total debt of $509.3 million.
     Summary of Indebtedness. The following table sets forth summary information related to our term loan credit facility, revolving credit facilities and retail credit facility at September 30, 2006:
                         
    As of September 30, 2006  
            (dollars in thousands)        
    Amount Outstanding     Total Facilities     Total Availability  
Debt, including current portion:
                       
Term loan credit facility
  $ 450,000     $ 550,000     $  
Revolving credit facilities
    8,134       455,000       245,735  
Retail credit facility
    51,159       51,159        
 
                 
Totals
  $ 509,293     $ 1,056,159     $ 245,735  
 
                 
     Revolving Credit Facility. We entered into a revolving credit facility on July 31, 2000, which was amended and restated on January 14, 2004 and further amended and restated on February 15, 2006. The Israel Discount Bank of New York, or Israel Discount Bank, acts as administrative agent, co-arranger, collateral agent and lender and Bank Leumi USA acts as co-arranger and lender under the revolving credit facility. The initial size of the

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revolving credit facility is $160.0 million with options to increase the size of the facility to $240.0 million if crude oil prices increase above certain levels or we increase our throughput capacity.
     Borrowing availability under the revolving credit facility is limited at any time to the lower of the total current size of the revolving credit facility at that time, which is initially $160.0 million, or the amount of the borrowing base under the revolving credit agreement. As of September 30, 2006, the borrowing base under the revolving credit facility was $244 million. The entire revolving credit facility is available in the form of letters of credit and revolving loans. The borrowings under the revolving credit facility bear interest at the Eurodollar rate plus 1.50% per annum. The revolving credit facility is jointly and severally guaranteed by all of our subsidiaries except for our retail subsidiaries. The revolving credit facility is secured by a first lien on cash, accounts receivables, inventories and related assets and a second lien on our fixed assets, excluding assets of our retail subsidiaries and of Paramount and its subsidiaries.
     No borrowings were outstanding under the revolving credit facility at September 30, 2006 and 2005. As of September 30, 2006 and 2005, there were $75.4 million and $130.2 million, respectively, of outstanding letters of credit under the revolving credit facility.
     Our revolving credit facility contains restrictive covenants, such as restrictions on change of control, creating liens, engaging in mergers, consolidations and sales of assets, incurring additional indebtedness, giving guaranties, engaging in different businesses, making loans and investments, entering into certain lease obligations, making certain capital expenditures and making certain dividend, debt and other restricted payments. However, these covenants do not restrict our activities so long as we maintain the financial covenants described below, on a pro-forma basis after giving effect to these activities. Our revolving credit facility also contains covenants that restrict us from compromising or adjusting receivables, engaging in certain transactions with affiliates and amending or waiving certain material agreements. The revolving credit facility contains financial covenants requiring us to maintain: a minimum consolidated tangible net worth; a ratio of total consolidated indebtedness less freely transferable cash and permitted investments; a minimum ratio of consolidated current assets to consolidated current liabilities; and a ratio of total consolidated EBITDA to consolidated interest expense.
     Compliance with these covenants is determined in the manner specified in the documentation governing the revolving credit facility. Consolidated EBITDA under our revolving credit facility represents net income plus minority interest, income tax expense, interest expense, depreciation and amortization and is measured each quarter on a rolling twelve-month basis.
     Credit Suisse Credit Facility. On June 22, 2006, we entered into a Credit Agreement with Credit Suisse (the “Credit Suisse Credit Facility”) with an aggregate available amount of $450 million. On August 4, 2006, we borrowed $400 million as a term loan upon consummation of the acquisition of Paramount and on September 28, 2006 we borrowed an additional $50 million as a term loan to finance the acquisition of Edgington. The loans under the Credit Suisse Credit Facility will mature on August 2, 2013.
     The borrowings under the Credit Suisse Credit Facility require a principal payment of 1% per annum to be paid in quarterly payments beginning September 30, 2006 with the balance due at maturity. The borrowings under the Credit Suisse Credit Facility bear interest at a Eurodollar rate plus 2.50% per annum. The interest rate may be reduced up to the Eurodollar rate plus 1.75% per annum based upon the ratings of the loans by Standard & Poor’s Rating Service and Moody’s Investors Service, Inc. The Credit Suisse Credit Facility is jointly and severally guaranteed by all of our subsidiaries except for our retail subsidiaries. The Credit Suisse Credit Facility is secured by a first lien on most of our assets, except for cash, accounts receivable and inventory, and a second lien on our cash, accounts receivable and inventory.
     We may, from time to time, request an additional $100 million provided that the sum of the incremental loans and the outstanding loans under the Credit Suisse Credit Facility does not exceed $550 million.
     We may prepay at any time a portion or all of the outstanding loan balance under the Credit Suisse Credit Facility with no prepayment premium.

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     The Credit Suisse Credit Facility contains restrictive covenants, such as restrictions on liens, mergers, consolidations, sales of assets, additional indebtedness, different businesses, certain lease obligations, and certain restricted payments. This facility does not contain any financial maintenance covenants.
     Wachovia Credit Facility. On June 6, 2006, our wholly-owned subsidiary SCS entered into a Credit Agreement (the “Wachovia Credit Facility”) by and among SCS, as borrower, and Wachovia Bank. Borrowings under the Wachovia Credit Facility are available in the form of (i) a term loan commitment in an aggregate principal amount of $30.0 million maturing on June 30, 2016, and (ii) a revolving credit commitment (available in the form of revolving loans and letters of credit) in an aggregate principal amount of $20.0 million maturing on June 30, 2009. Revolving loans may be converted by SCS at any time to a term loan maturing on the tenth anniversary of conversion. At the request of SCS, the revolving credit commitment may be increased by an amount not to exceed $10.0 million. The aggregate amount of the lenders’ commitments under the entire Wachovia Credit Facility may not exceed $60.0 million. On July 3, 2006, SCS borrowed $50.0 million of which $30.2 million was used to refinance existing debt and approximately $19.8 million was used to finance the acquisition of Good Time Stores. At September 30, 2006, the outstanding balances were $30.0 million in the form of a term loan and $20.0 million in the form of a revolving loan.
     Borrowings under the Wachovia Credit Facility bear interest at a Eurodollar rate plus 1.5% per annum. Principal payments of term loan borrowings under this credit facility are being paid in monthly installments based on a 15 year amortization term.
     Obligations under the Wachovia Credit Facility are jointly and severally guaranteed by us, our wholly-owned subsidiaries Alon USA Interests, LLC and the subsidiaries of SCS. The obligations under the Wachovia Credit Facility are secured by a pledge of substantially all of the assets of SCS and its subsidiaries, including cash, accounts receivable and inventory.
     The Wachovia Credit Facility includes a financial covenant that requires us to maintain a ratio of total consolidated EBITDA less income tax expense in cash to total consolidated scheduled principal payments of indebtedness plus interest expense, as of the end of each fiscal year, of not less than 1.25 to 1.0. Compliance with this covenant is determined in the manner specified in the documentation governing the credit facility. Consolidated EBITDA under the Wachovia Credit Facility represents net income plus depreciation, amortization, taxes, interest expense and minority interest, less gain on disposition of assets.
     The Wachovia Credit Facility contains customary restrictive covenants on the activities of SCS and its subsidiaries, such as restrictions on liens, mergers, consolidations, sales of assets, additional indebtedness, different businesses, certain lease obligations, and certain restricted payments.
     Revolving Credit Facility – Paramount. Paramount has a Revolving Credit Agreement (“Paramount Credit Facility”) with a group of financial institutions, which is secured by the current assets of Paramount. The Paramount Credit Facility expires on January 15, 2007. On July 26, 2005, the Paramount Credit Facility was amended and restated to increase the available borrowings up to $190.0 million, and was further amended and restated on June 22, 2006 to increase the available borrowings up to $215.0 million, consisting of revolving loans and letters of credit. Amounts borrowed under the Paramount Credit Facility accrue interest at the Eurodollar plus 2.5%. The borrowings outstanding under the Paramount Credit Facility at September 30, 2006 were $8.1 million and outstanding letters of credit were $125.7 million.
     Paramount is required to comply with certain restrictive covenants related to working capital and operations under the Paramount Credit Facility as well as financial covenants relating to the current ratio, tangible net worth and a debt service coverage ratio.
Capital Spending
     Each year our Board of Directors approves capital projects, including regulatory and planned turnaround projects that our management is authorized to undertake in our annual capital budget. Additionally, at times when conditions warrant or as new opportunities arise, other projects or the expansion of existing projects may be approved. Our total capital expenditure and turnaround/chemical catalyst budget for 2006 is $38.2 million, of which $12.8 million related to regulatory and compliance projects, $2.9 million related to turnaround and chemical

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catalyst, and $10.4 million for various improvement and sustaining projects, had been spent as of September 30, 2006.
     Clean Air Capital Expenditures. We expect to spend approximately $15.4 million over the next four years to comply with the Federal Clean Air Act regulations requiring a reduction in sulfur content in gasoline.
     Turnaround and Chemical Catalyst Costs. We completed a major turnaround at our Big Spring refinery on substantially all of our major processing units, including the crude unit and the fluid catalytic cracking unit and chemical catalyst replacement in the first week of March 2005, at a cost of approximately $10.4 million. We expect to spend approximately $4.4 million for chemical catalyst replacement in 2006, including the $3.0 million of chemical catalyst expenditures as of September 30, 2006.
Contractual Obligations and Commercial Commitments
     There have been no material changes outside the ordinary course of business from our contractual obligations and commercial commitments detailed in our annual report on Form 10-K for the year ended December 31, 2005 with the exception of the following:
  the prepayment of our $100 million term loan due January 14, 2009 with available cash on hand on January 19, 2006;
 
  on March 1, 2006, we sold our Amdel and White Oil pipelines, which had been inactive since December 2002, to an affiliate of Sunoco Logistics Partners L.P. (“Sunoco”) for total consideration of approximately $68 million. In conjunction with this transaction, we entered into a 10-year pipeline Throughput and Deficiency Agreement with Sunoco, with an option to extend the agreement by four additional 30-month periods. The Throughput and Deficiency Agreement will allow us to maintain our physically integrated system by retaining crude oil transportation rights in the pipelines from the Gulf Coast. Pursuant to the Throughput and Deficiency Agreement, we have agreed to ship, starting June 1, 2006, a minimum of 15,000 bpd in the pipelines during the term of the agreement;
 
  the draw down of $50 million under our credit facility with Wachovia Bank in conjunction with the Good Time Stores acquisition;
 
  the draw down of $450 million under our credit facility with Credit Suisse in conjunction with the Paramount and Edgington acquisitions; and
 
  our obligations under the Paramount Credit Facility assumed in conjunction with the Paramount acquisition.
Off-Balance Sheet Arrangements
    We have no off-balance sheet arrangements.
Critical Accounting Policies
     We prepare our consolidated financial statements in conformity with GAAP. In order to apply these principles, we must make judgments, assumptions and estimates based on the best available information at the time. Actual results may differ based on the accuracy of the information utilized and subsequent events, some of which we may have little or no control over.
     Our critical accounting policies are described under the caption “Management’s Discussion and Analysis of Financial Condition and Results of Operations—Critical Accounting Policies” in our annual report on Form 10-K for the year ended December 31, 2005. Certain critical accounting policies that materially affect the amounts recorded in our consolidated financial statements are the use of LIFO method for valuing certain inventories and the deferral and subsequent amortization of costs associated with major turnarounds and chemical catalysts replacements. No significant changes to these accounting policies have occurred subsequent to December 31, 2005.

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New Accounting Standards and Disclosures
     Disclosed in footnote 1(c) Basis of Presentation and Certain Significant Accounting Policies - New Accounting Standards.

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ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
     Changes in commodity prices, purchased fuel prices and interest rates are our primary sources of market risk. Our risk management committee oversees all activities associated with the identification, assessment and management of our market risk exposure.
Commodity Price Risk
     We are exposed to market risks related to the volatility of crude oil and refined product prices, as well as volatility in the price of natural gas used in our refinery operations. Our financial results can be affected significantly by fluctuations in these prices, which depend on many factors, including demand for crude oil, gasoline and other refined products, changes in the economy, worldwide production levels, worldwide inventory levels and governmental regulatory initiatives. Our risk management strategy identifies circumstances in which we may utilize the commodity futures market to manage risk associated with these price fluctuations.
     In order to manage the uncertainty relating to inventory price volatility, we have consistently applied a policy of maintaining inventories at or below a targeted operating level. In the past, circumstances have occurred, such as timing of crude oil cargo deliveries, turnaround schedules or shifts in market demand that have resulted in variances between our actual inventory level and our desired target level. Upon the review and approval of our risk management committee, we may utilize the commodity futures market to manage these anticipated inventory variances.
     We maintain inventories of crude oil, feedstocks and refined products, the values of which are subject to wide fluctuations in market prices driven by world economic conditions, regional and global inventory levels and seasonal conditions. As of September 30, 2006, we held approximately 4.1 million barrels of crude and product inventories valued under the LIFO valuation method with an average cost of $51.21 per barrel. Market value exceeded carrying value of LIFO costs by $42.8 million. We refer to this excess as our LIFO reserve. If the market value of these inventories had been $1.00 per barrel lower, our LIFO reserve would have been reduced by $4.1 million.
     In accordance with SFAS No. 133, all commodity futures contracts are recorded at fair value and any changes in fair value between periods is recorded in the profit and loss section of our consolidated financial statements. “Forwards” represent physical trades for which pricing and quantities have been set, but the physical product delivery has not occurred by the end of the reporting period. “Futures” represent trades which have been executed on the New York Mercantile Exchange which have not been closed or settled at the end of the reporting period. A “long” represents an obligation to purchase product and a “short” represents an obligation to sell product.
     The following table provides information about our derivative commodity instruments as of September 30, 2006:
                                                 
                    Wtd Avg            
            Wtd Avg   Fair            
Description   Contract   Purchase   Market   Contract   Fair   Gain
of Activity   Volume   Price/BBL   Price   Value   Value   (Loss)
                            (in thousands)
Futures-long
        $     $     $     $     $  
Forwards-long (crude)
    11,750       62.44       50.94       734       599       135  
Forwards-long (refined products)
    25,000       78.42       76.01       1,961       1,901       (60 )
Forwards-long (asphalt)
    35,600       63.33       65.39       2,255       2,328       73  
Interest Rate Risk.
     As of September 30, 2006, none of our outstanding debt was at floating interest rates.

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ITEM 4. CONTROLS AND PROCEDURES
     (1) Evaluation of disclosure controls and procedures.
          Our management has evaluated, with the participation of our principal executive and principal financial officers, the effectiveness of our disclosure controls and procedures (as defined in Rule 13a-15(e) under the Securities Exchange Act of 1934) as of the end of the period covered by this report, and has concluded that our disclosure controls and procedures are effective to provide reasonable assurance that information required to be disclosed by us in the reports that we file or submit under the Exchange Act is recorded, processed, summarized and reported, within the time periods specified in the Securities and Exchange Commission’s rules and forms.
     (2) Changes in internal control over financial reporting.
          There has been no change in our internal control over financial reporting (as described in Rule 13a-15(f) under the Exchange Act) that occurred during our last fiscal quarter that has materially affected, or is reasonably likely to materially affect, our internal control over financial reporting.

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PART II. OTHER INFORMATION
ITEM 6. EXHIBITS
     
Exhibit    
Number   Description of Exhibit
 
   
3.1
  Amended and Restated Certificate of Incorporation of Alon USA Energy, Inc. (incorporated by reference to Exhibit 3.1 to Form S-1, filed by the Company on July 7, 2005, SEC File No. 333-124797).
 
   
3.2
  Amended and Restated Bylaws of Alon USA Energy, Inc. (incorporated by reference to Exhibit 3.2 to Form S-1, filed by the Company on July 14, 2005, SEC File No. 333-124797).
 
   
4.1
  Specimen Common Stock Certificate (incorporated by reference to Exhibit 4.1 to Form S-1, filed by the Company on June 17, 2005, SEC File No. 333-124797).
 
   
10.1*
  First Amendment to Stock Purchase Agreement, dated June 30, 2006, by and among Alon USA Energy, Inc., The Craig C. Barto and Gisele M. Barto Living Trust, Dated April 5, 1991, The Jerrel C. Barto and Janice D. Barto Living Trust, Dated March 18, 1991, W. Scott Lovejoy III and Mark R. Milano.
 
   
10.2*
  Second Amendment to Stock Purchase Agreement, dated July 31, 2006, by and among Alon USA Energy, Inc., The Craig C. Barto and Gisele M. Barto Living Trust, Dated April 5, 1991, The Jerrel C. Barto and Janice D. Barto Living Trust, Dated March 18, 1991, W. Scott Lovejoy III and Mark R. Milano.
 
   
10.3
  Amended and Restated Credit Agreement, dated July 26, 2005, by and among Paramount Petroleum Corporation, Bank of America, N.A. and Société Générale (incorporated by reference to Exhibit 10.1 to Form 8-K, filed by the Company on August 9, 2006, SEC File No. 001-32567).
 
   
10.4
  First Amendment to Amended and Restated Credit Agreement, dated January 26, 2006, by and among Paramount Petroleum Corporation, Bank of America, N.A. and the lenders party thereto (incorporated by reference to Exhibit 10.2 to Form 8-K, filed by the Company on August 9, 2006, SEC File No. 001-32567).
 
   
10.5
  Second Amendment to Amended and Restated Credit Agreement, dated February 28, 2006, by and among Paramount Petroleum Corporation, Bank of America, N.A. and the lenders party thereto (incorporated by reference to Exhibit 10.3 to Form 8-K, filed by the Company on August 9, 2006, SEC File No. 001-32567).
 
   
10.6
  Third Amendment to Amended and Restated Credit Agreement, dated June 12, 2006, by and among Paramount Petroleum Corporation, Bank of America, N.A. and the lenders party thereto (incorporated by reference to Exhibit 10.4 to Form 8-K, filed by the Company on August 9, 2006, SEC File No. 001-32567).
 
   
10.7
  Fourth Amendment to Amended and Restated Credit Agreement, dated June 16, 2006, by and among Paramount Petroleum Corporation, Bank of America, N.A. and the lenders party thereto (incorporated by reference to Exhibit 10.5 to Form 8-K, filed by the Company on August 9, 2006, SEC File No. 001-32567).
 
   
10.8
  Fifth Amendment to Amended and Restated Credit Agreement, dated June 22, 2006, by and among Paramount Petroleum Corporation, Bank of America, N.A., Banc of America Securities LLC and the lenders party thereto (incorporated by reference to Exhibit 10.6 to Form 8-K, filed by the Company on August 9, 2006, SEC File No. 001-32567).

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Exhibit    
Number   Description of Exhibit
 
   
10.9
  Amended and Restated Management Employment Agreement, dated as of August 9, 2006, between Harlin R. Dean and Alon USA GP, LLC (incorporated by reference to Exhibit 10.1 to Form 8-K filed by the Company on August 9, 2006, SEC File No. 001-32567).
 
   
31.1*
  Certifications of Chief Executive Officer pursuant to §302 of the Sarbanes-Oxley Act of 2002.
 
   
31.2*
  Certifications of Chief Financial Officer pursuant to §302 of the Sarbanes-Oxley Act of 2002.
 
   
32.1*
  Certifications of Chief Executive Officer and Chief Financial Officer pursuant to 18 U.S.C. §1350, as adopted pursuant to §906 of the Sarbanes-Oxley Act of 2002.
 
*   Furnished herewith.

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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.
         
     
Date: November 14, 2006  By:   /s/ David Wiessman    
    David Wiessman   
    Executive Chairman   
 
         
     
Date: November 14, 2006  By:   /s/ Jeff D. Morris    
    Jeff D. Morris   
    Chief Executive Officer   
 
         
     
Date: November 14, 2006  By:   /s/ Shai Even    
    Shai Even   
    Chief Financial Officer   

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EXHIBITS
     
Exhibit    
Number   Description of Exhibit
 
   
3.1
  Amended and Restated Certificate of Incorporation of Alon USA Energy, Inc. (incorporated by reference to Exhibit 3.1 to Form S-1, filed by the Company on July 7, 2005, SEC File No. 333-124797).
 
   
3.2
  Amended and Restated Bylaws of Alon USA Energy, Inc. (incorporated by reference to Exhibit 3.2 to Form S-1, filed by the Company on July 14, 2005, SEC File No. 333-124797).
 
   
4.1
  Specimen Common Stock Certificate (incorporated by reference to Exhibit 4.1 to Form S-1, filed by the Company on June 17, 2005, SEC File No. 333-124797).
 
   
10.1*
  First Amendment to Stock Purchase Agreement, dated June 30, 2006, by and among Alon USA Energy, Inc., The Craig C. Barto and Gisele M. Barto Living Trust, Dated April 5, 1991, The Jerrel C. Barto and Janice D. Barto Living Trust, Dated March 18, 1991, W. Scott Lovejoy III and Mark R. Milano.
 
   
10.2*
  Second Amendment to Stock Purchase Agreement, dated July 31, 2006, by and among Alon USA Energy, Inc., The Craig C. Barto and Gisele M. Barto Living Trust, Dated April 5, 1991, The Jerrel C. Barto and Janice D. Barto Living Trust, Dated March 18, 1991, W. Scott Lovejoy III and Mark R. Milano.
 
   
10.3
  Amended and Restated Credit Agreement, dated July 26, 2005, by and among Paramount Petroleum Corporation, Bank of America, N.A. and Société Générale (incorporated by reference to Exhibit 10.1 to Form 8-K, filed by the Company on August 9, 2006, SEC File No. 001-32567).
 
   
10.4
  First Amendment to Amended and Restated Credit Agreement, dated January 26, 2006, by and among Paramount Petroleum Corporation, Bank of America, N.A. and the lenders party thereto (incorporated by reference to Exhibit 10.2 to Form 8-K, filed by the Company on August 9, 2006, SEC File No. 001-32567).
 
   
10.5
  Second Amendment to Amended and Restated Credit Agreement, dated February 28, 2006, by and among Paramount Petroleum Corporation, Bank of America, N.A. and the lenders party thereto (incorporated by reference to Exhibit 10.3 to Form 8-K, filed by the Company on August 9, 2006, SEC File No. 001-32567).
 
   
10.6
  Third Amendment to Amended and Restated Credit Agreement, dated June 12, 2006, by and among Paramount Petroleum Corporation, Bank of America, N.A. and the lenders party thereto (incorporated by reference to Exhibit 10.4 to Form 8-K, filed by the Company on August 9, 2006, SEC File No. 001-32567).
 
   
10.7
  Fourth Amendment to Amended and Restated Credit Agreement, dated June 16, 2006, by and among Paramount Petroleum Corporation, Bank of America, N.A. and the lenders party thereto (incorporated by reference to Exhibit 10.5 to Form 8-K, filed by the Company on August 9, 2006, SEC File No. 001-32567).
 
   
10.8
  Fifth Amendment to Amended and Restated Credit Agreement, dated June 22, 2006, by and among Paramount Petroleum Corporation, Bank of America, N.A., Banc of America Securities LLC and the lenders party thereto (incorporated by reference to Exhibit 10.6 to Form 8-K, filed by the Company on August 9, 2006, SEC File No. 001-32567).
 
   
10.9
  Amended and Restated Management Employment Agreement, dated as of August 9, 2006, between Harlin R. Dean and Alon USA GP, LLC (incorporated by reference to Exhibit 10.1 to Form 8-K, filed by the Company on August 9, 2006, SEC File No. 001-32567).

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Exhibit    
Number   Description of Exhibit
 
   
31.1*
  Certifications of Chief Executive Officer pursuant to §302 of the Sarbanes-Oxley Act of 2002.
 
   
31.2*
  Certifications of Chief Financial Officer pursuant to §302 of the Sarbanes-Oxley Act of 2002.
 
   
32.1*
  Certifications of Chief Executive Officer and Chief Financial Officer pursuant to 18 U.S.C. §1350, as adopted pursuant to §906 of the Sarbanes-Oxley Act of 2002.
 
*   Furnished herewith.

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