Alon Refining Krotz Springs 10-K 2012 Q4 Annual report

UNITED STATES SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-K

(Mark One)

þ	ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
	FOR THE FISCAL YEAR ENDED DECEMBER 31, 2012

OR

o	ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
	FOR THE TRANSITION PERIOD FROM __________TO __________

Commission file number: 333-163942

ALON REFINING KROTZ SPRINGS, INC.

(Exact name of Registrant as specified in its charter)

Delaware (State of incorporation)	74-2849682 (I.R.S. Employer Identification No.)
12700 Park Central Dr., Suite 1600, Dallas, Texas (Address of principal executive offices)	75251 (Zip Code)

Registrant’s telephone number, including area code: (972) 367-3600

Securities registered pursuant to Section 12 (b) of the Act: None.

Securities registered pursuant to Section 12 (g) of the Act: None.

Indicate by check mark if the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act. Yes o No þ

Indicate by check mark if the registrant is not required to file reports pursuant to Section 13 or Section 15(d) of the Act. Yes þ No o

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 has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§ 232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files). Yes þ No o

Indicate by check mark if disclosure of delinquent filers pursuant to Item 405 of Regulation S-K is not contained herein, and will not be contained, to the best of registrant’s knowledge, in definitive proxy or information statements incorporated by reference in Part III of this Form 10-K or any amendment to this Form 10-K. þ

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, or a smaller reporting company. See the definitions of “large accelerated filer,” “accelerated filer” and “smaller reporting company” in Rule 12b-2 of the Exchange Act. (Check one):

Large accelerated filer o	Accelerated filer o	Non-accelerated filer þ	Smaller reporting company o
		(Do not check if a smaller reporting company)

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 registrant is a subsidiary of Alon USA Energy, Inc., a Delaware corporation, and there is no market for the registrant's common stock. As of March 1, 2013, 50,111 shares of the registrant's Class A common stock, par value $0.01, and 90 shares of the registrant's Class B common stock, par value $0.01, were outstanding.

The aggregate market value for the registrant’s common stock held by non-affiliates as of June 30, 2012, the last day of the registrant’s most recently completed second fiscal quarter was $0.

The registrant meets the conditions set forth in General Instruction I(1) (a) and (b) of Form 10-K and is therefore filing this Form with the reduced disclosure format permitted by General Instruction I(2).

Documents incorporated by reference: None.

TABLE OF CONTENTS

PART I
ITEMS 1. AND 2. BUSINESS AND PROPERTIES	1
ITEM 1A. RISK FACTORS	5
ITEM 1B. UNRESOLVED STAFF COMMENTS	11
ITEM 3. LEGAL PROCEEDINGS	11
ITEM 4. MINE SAFETY DISCLOSURES	11
PART II
ITEM 5. MARKET FOR REGISTRANT'S COMMON EQUITY, RELATED STOCKHOLDER MATTERS AND ISSUER PURCHASES OF EQUITY SECURITIES	12
ITEM 6. SELECTED FINANCIAL DATA	12
ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS	12
ITEM 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK	18
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA	19
ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND FINANCIAL DISCLOSURE	19
ITEM 9A. CONTROLS AND PROCEDURES	20
ITEM 9B. OTHER INFORMATION	20
PART III
ITEM 10. DIRECTORS, EXECUTIVE OFFICERS AND CORPORATE GOVERNANCE	21
ITEM 11. EXECUTIVE COMPENSATION	23
ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT AND RELATED STOCKHOLDER MATTERS	24
ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS AND DIRECTOR INDEPENDENCE	24
ITEM 14. PRINCIPAL ACCOUNTANT FEES AND SERVICES	25
PART IV
ITEM 15. EXHIBITS AND FINANCIAL STATEMENT SCHEDULES	26
EX-23.1 CONSENT OF KPMG LLP
EX-31.1 CERTIFICATION OF CEO PURSUANT TO SECTION 302
EX-31.2 CERTIFICATION OF CFO PURSUANT TO SECTION 302
EX-32.1 CERTIFICATION OF CEO AND CFO PURSUANT TO SECTION 906

PART I

ITEMS 1. AND 2. BUSINESS AND PROPERTIES.

Statements in this Annual Report on Form 10-K, including those in Items 1 and2, “Business and Properties,” and Item 3, “Legal Proceedings,” that are nothistorical in nature should be deemed forward-looking statements that areinherently uncertain. See “Forward-Looking Statements” in “Management'sDiscussion and Analysis of Financial Condition and Results of Operations” inItem 7 for a discussion of forward-looking statements and of factors that couldcause actual outcomes and results to differ materially from those projected.

This Annual Report on Form 10-K and other Securities and Exchange Commission filings of Alon Refining Krotz Springs, Inc. occasionally make references to our parent company, Alon USA Energy, Inc. (“Alon USA”), when describing actions, rights or obligations. These references reflect the fact that Alon Refining Krotz Springs, Inc. is consolidated with its respective parent company for financial reporting purposes. However, these references should not be interpreted to imply that the parent company is actually undertaking the action or has the rights or obligations of the relevant subsidiary company or that the subsidiary company is undertaking an action or has the rights or obligations of its parent company or any other affiliate.

Company Overview

In this Annual Report, the words “we,” “our” and “us” refer to Alon Refining Krotz Springs, Inc., and not to any other person.

We are a Delaware corporation formed in May 2008 in connection with the acquisition of Valero Refining Company-Louisiana by Alon USA. We own and operate a high conversion crude oil refinery with a crude oil throughput capacity of approximately 83,100 barrels per day (“bpd”) in Krotz Springs, Louisiana. Our principal executive offices are located at 12700 Park Central Dr., Suite 1600, Dallas, Texas 75251, and our telephone number is (972) 367-3600.

We file annual, quarterly and current reports, and file or furnish other information, with the Securities Exchange Commission (“SEC”). Our SEC filings are available to the public over the Internet at the SEC's website at www.sec.gov. In addition, our SEC filings are available free of charge through our parent company's internet website at www.alonusa.com as soon as reasonably practicable after we electronically file, or furnish, such material with the SEC. We will provide copies of our filings free of charge to our bondholders upon request to Alon Refining Krotz Springs, Inc., Attention: Investor Relations, 12700 Park Central Dr., Suite 1600, Dallas, Texas 75251.

Business

Our Refinery

In July 2008 we acquired Valero Refining Company — Louisiana. Valero Refining Company — Louisiana’s assets included a refinery with a nameplate capacity of approximately 83,100 bpd located in Krotz Springs, Louisiana.

Our refinery is strategically located on approximately 381 acres on the Atchafalaya River in central Louisiana at the intersection of two crude oil pipeline systems and has direct access to the Colonial products pipeline system (“Colonial Pipeline”), providing us with diversified access to both locally sourced and foreign crude oils, as well as distribution of our products to markets throughout the Southern and Eastern United States and along the Mississippi and Ohio Rivers. In industry terms, our refinery is characterized as a “mild residual cracking refinery,” which generally refers to a refinery utilizing vacuum distillation and catalytic cracking processes in addition to basic distillation and naphtha reforming processes to minimize low quality black oil production and to produce higher light product yields such as gasoline, light distillates and intermediate products.

The refinery processing units are structured to yield approximately 101.5% of total feedstock input, meaning that for each 100 barrels of crude oil and feedstocks input into the refinery, it produces 101.5 barrels of refined products. Of the 101.5%, on average 99.0% is light finished products such as gasoline and distillates, including diesel and jet fuel, petrochemical feedstocks and liquefied petroleum gas, and the remaining 2.5% is primarily heavy oils.

The refinery’s main processing units include a crude unit and an associated vacuum unit, a fluid catalytic cracking unit, a catalytic reformer unit, a polymerization unit, and an isomerization unit.

Our refinery has the capability to process substantial volumes of low sulfur, or sweet, crude oils to produce a high percentage of light, high-value refined products. Typically, sweet crude oil has accounted for 100% of our refinery’s crude oil input.

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Raw Material Supply.

In 2012, our refinery received crude oil from West Texas through the Amdel pipeline, which terminates at the Nederland terminal. The crude oil is then transported from the Nederland terminal to our refinery via the Intracoastal Canal and the Atchafalaya River. Our refinery also has access to various types of domestic and foreign crude oils via an ExxonMobil pipeline (“EMPCo”), barge delivery, and truck rack delivery. Approximately 52% of the crude oil is received by pipeline with the remainder received by barge or truck.

We receive Light Louisiana Sweet ("LLS") and foreign crude oils from the EMPCo “Northline System.” The Northline System delivers LLS and foreign crude oils from the St. James, Louisiana crude oil terminalling complex.

In 2012, sweet crude oil accounted for all of the crude oil inputs at our refinery, of which approximately 70.0% was Gulf Coast sweet crude oils and 30.0% was WTI priced crude oil.

Historically, approximately three-quarters of our refinery’s crude oil input requirements are purchased through term contracts with several suppliers. At present, J. Aron & Company ("J. Aron"), through arrangements with various oil companies, supplies the majority of our refinery’s crude oil input requirements. Other feedstocks, including butane and secondary feedstocks, are delivered by truck and marine transportation.

Production

Gasoline. In 2012, gasoline accounted for approximately 42.4% of our refinery’s production. We produce 87 octane regular unleaded gasoline and use a computerized component blending system to optimize gasoline blending. Our refinery is capable of producing regular unleaded gasoline grades required in the Southern and Eastern U.S. markets.

Distillates. In 2012, diesel, light cycle oil and jet fuel accounted for approximately 41.4% of our refinery’s production. In connection with the acquisition of our refinery in 2008, we entered into an offtake agreement with Valero Energy Corporation (“Valero”) that provides for Valero to purchase, at market prices, light cycle oil and high sulfur distillate blendstock for a period of five years.

Heavy Oils and Other. In 2012, slurry oil, LPG and petrochemical feedstocks accounted for approximately 16.2% of our refinery’s production.

Sales

Transportation Fuel Marketing. Substantially all of the refined products produced by our refinery are sold to J. Aron as they are produced. We market transportation fuel production through bulk sales and exchange channels. These bulk sales and exchange arrangements are entered into with various oil companies and traders and are transported to markets on the Mississippi River and the Atchafalaya River as well as to the Colonial Pipeline.

Product Pipelines. Our refinery connects to and distributes refined products into the Colonial Pipeline for distribution by our customers to the Southern and Eastern United States. The 5,519 mile Colonial Pipeline transports products to 267 marketing terminals located near the major population centers. The connection to the Colonial Pipeline provides flexibility to optimize product flows into multiple regional markets.

Barge, Railcar and Truck. Products not shipped through the Colonial Pipeline, such as high sulfur diesel sold to Valero pursuant to our offtake agreement, are transported via barge for sale. Barges have access to both the Mississippi and Ohio Rivers.

Propylene/propane mix is sold via railcar and truck, to consumers at Mont Belvieu, Texas or in adjacent Louisiana markets. Mixed LPGs are shipped to an LPG fractionator at Napoleonsville, Louisiana. We pay a fractionation fee and sell the ethane and propane to a regional chemical company under contract, transport the normal butane back to our refinery via truck for blending, and sell the isobutane and natural gasoline on a spot basis.

Parent Company

Alon USA is an independent refiner and marketer of petroleum products operating primarily in the South Central, Southwestern and Western regions of the United States. Alon USA is listed on the NYSE under the symbol “ALJ” and had a market capitalization of $1,068.6 million as of December 31, 2012. Alon USA directly owns crude oil refineries located in California, Oregon and Louisiana and, through its ownership of 81.6% of the common units of Alon USA Partners, LP (NYSE: ALDW), a crude oil refinery in Texas. These refineries have a combined throughput capacity of approximately 250,000 bpd. Alon USA's refineries produce petroleum products including various grades of gasoline, diesel fuel, jet fuel, petrochemicals, petrochemical feedstocks, asphalt and other petroleum-based products.

The acquisition of our refinery in 2008 increased Alon USA's refining capacity by approximately 50% and provided Alon USA with further scale, diversification and flexibility to optimize feedstock and refined product mixes. Furthermore, our

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refinery's strategic location in central Louisiana provided geographic diversification as well as increased opportunities for refined product marketing and distribution.

In addition to its refining operations, Alon USA operates 298 convenience stores and markets motor fuels to over 640 locations, including Alon USA's convenience stores, under the Alon brand name in the South Central and Southwestern United States. Alon USA also markets asphalt products produced at its Big Spring, Willbridge and California refineries through 11 refinery/terminal locations in Texas (Big Spring), California (Paramount, Long Beach, Elk Grove, Bakersfield and Mojave), Oregon (Willbridge), Washington (Richmond Beach), Arizona (Phoenix and Flagstaff) and Nevada (Fernley) (50% interest) as well as a 50% interest in Wright Asphalt Products Company, LLC. Alon USA, through its retail subsidiaries, is also the largest 7-Eleven licensee in the United States.

Competition

The petroleum refining industry continues to be highly competitive. Many of our principal competitors are integrated, multi-national oil companies (e.g., Valero, Chevron, ExxonMobil, Shell, ConocoPhillips and BP) and other major independent refining and marketing entities that operate in our market areas. Because of their diversity, integration of operations and larger capitalization, these major competitors may have greater financial and other resources and may have a greater ability to bear the economic risks, operating risks and volatile market conditions associated with the petroleum refining industry.

All of our crude oil and feedstocks are purchased from third-party sources, while some of our vertically-integrated competitors have their own sources of crude oil that they may use to supply their refineries.

Substantially all of the refined products produced by our refinery are sold to J. Aron as they are produced. The majority of our refined fuel products produced at our refinery are sold on the spot market and shipped through the Colonial Pipeline to major demand centers throughout the Southern and Eastern United States. The market for refined products in these regions is also supplied by a number of refiners, including large integrated oil companies or independent refiners, that either have refineries located in the region or have pipeline access to these regions. These larger companies typically have greater resources and may have greater flexibility in responding to volatile market conditions or absorbing market changes.

Financial returns in the refining and marketing industry depend on the difference between refined product prices and the prices for crude oil and other feedstock, also referred to as refining margins. Refining margins are impacted by, among other things, levels of crude oil and refined product inventories, balance of supply and demand, utilization rates of refineries and global economic and political events.

Government Regulation and Legislation

Environmental Controls and Expenditures

Our operations are subject to extensive and frequently changing federal, state, regional and local laws, regulations and ordinances relating to the protection of the environment, including those governing emissions or discharges to the air, land and water, the handling and disposal of solid and hazardous waste and the remediation of contamination. We believe our operations are generally in substantial compliance with these requirements. Over the next several years our operations will have to meet new requirements being promulgated by the United States Environmental Protection Agency ("EPA") and the states and jurisdictions in which we operate.

The Clean Air Act and its implementing regulations require significant reductions in the sulfur content in gasoline and diesel fuel. These regulations required most refineries to reduce the sulfur content in gasoline to 30 ppm and diesel to 15 ppm. Gasoline produced at our refinery currently meets the low sulfur gasoline standard. We do not manufacture low sulfur diesel fuel.

In 2007, the EPA adopted final rules to reduce the levels of benzene in gasoline on a nationwide basis. More specifically, beginning in 2011, refiners were required to meet an annual average gasoline benzene content standard of 0.62%, which may be achieved through the purchase of benzene credits, and that beginning on July 1, 2012 refiners were required to meet a maximum average gasoline benzene concentration of 1.30%, by volume on all gasoline produced, both reformulated and conventional and without benzene credits. We have spent $10.3 million through 2012 in order for our refinery to install controls to meet the standards. On April 12, 2012, the EPA granted an extension of time through December 31, 2012 to comply with the annual average standard at our refinery.

We are subject to the renewable fuel standard which requires refiners to blend renewable fuels (e.g., ethanol, biodiesel) into their finished transportation fuels or purchase renewable energy credits, called RINs, in lieu of blending. The EPA generally establishes new annual renewable fuel percentage standards for each compliance year in the preceding year. For 2012, the EPA raised the renewable fuel percentage standard to approximately 9%. The EPA has not yet finalized the 2013 renewable fuel percentage standard, but has proposed to raise it to approximately 9.6%. Our refinery has received an extension

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of the deadline to comply with the renewable fuel standard. Therefore, we have not been required to blend renewable fuels or purchase RINs for compliance until 2013.

Regulation

Conditions may develop that require additional capital expenditures at our refinery for compliance with the Federal Clean Air Act and other federal, state and local requirements. We cannot currently determine the amounts of such future expenditures.

Compliance

The EPA has adopted regulations requiring certain new or modified sources of high-volume greenhouse gases ("GHG") emissions to install best achievable control technology to reduce GHG emissions. If we undertake significant improvements at our refinery that could result in an increase in GHG emissions, we could be required under EPA’s regulations to install expensive GHG emissions control equipment. Although Congress has from time to time considered adopting legislation to reduce emissions of GHGs through establishment of a market-based “cap and trade” system that would be designed to achieve yearly reductions in GHG emissions, no such legislation has been passed. While it is possible that Congress will adopt some form of federal mandatory GHG emission reductions legislation in the future, the timing and specific requirements of any such legislation are uncertain at this time.

Our refinery was subject to a “global settlement” with the EPA under the National Petroleum Refining Initiative, at the time it was acquired. In return for agreeing to the consent decree and implementing the reductions in emissions that it specifies, the refineries secured broad releases of liability that provide immunity from enforcement actions for alleged past non-compliance under each of the Clean Air Act programs covered by the consent decree. If we are unable to meet the agreed upon reductions without add-on controls, our capital costs could increase. Because our refinery remains subject to the Valero consent decree, we entered into an agreement with Valero at the time of the acquisition allocating responsibilities under the consent decree. We are responsible for implementing only those portions of the consent decree that are specifically and uniquely applicable to our refinery.

Known Environmental Liabilities

At December 31, 2012, our refinery had an environmental reserve of $0.3 million. This reserve relates to the remediation of groundwater.

Employees

Approximately 190 people, including operations personnel and general and administrative personnel, are currently utilized to conduct and support our refinery's operations. To facilitate and lower the costs of the provision and administration of employee payroll and benefits, the personnel utilized in our operations are employed through an affiliate of Alon USA with our company paying the costs of such payroll and benefits. None of our personnel are covered by collective bargaining agreements. We believe that our relations with our personnel are satisfactory.

Properties

Our principal real property consists of approximately 260 acres of owned real property, which includes the land upon which our main refinery facilities are located and land adjacent thereto. In addition, we lease approximately 160 acres of land near and adjoining our refinery, which are used for activities ancillary to and in support of our refinery. The leased property is primarily held under five main leases, with current terms ranging from three to 20 years and options to permit the renewal of the leases for the majority of such leased property. The shortest term of any such lease without a renewal right runs through December 31, 2017. We believe that our facility is sufficient for our operations and is maintained in a good state of repair in the ordinary course of business.

Insurance

We are insured under our own insurance policies which cover physical damage (all risk property damage, business interruption and flood), third party liability and other miscellaneous items. The property insurance policy has a combined loss limit for a property loss and business interruption at our refinery of $850 million per occurrence. A deductible of $2 million applies to physical damage claims, with a 45-day wait period deductible for business interruption.

Litigation

There is no material litigation pertaining to our Company.

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ITEM 1A. RISK FACTORS.

The occurrence of any of the events described in this Risk Factors section and elsewhere in this Annual Report on Form 10-K or in any other of our filings with the SEC could have a material adverse effect on our business, financial position, results of operations and cash flows. In evaluating an investment in any of our securities, you should consider carefully, among other things, the factors and the specific risks set forth below. This Annual Report on Form 10-K contains forward-looking statements that involve risks and uncertainties. See “Forward-Looking Statements” in “Management’s Discussion and Analysis of Financial Condition and Results of Operations” in Item 7 for a discussion of the factors that could cause actual results to differ materially from those projected.

Risk Factors Relating to Our Business

The price volatility of crude oil, other feedstocks, refined products and fuel and utility services may have a material adverse effect on our earnings, profitability and cash flows.

Our refining earnings, profitability and cash flows from operations depend primarily on the margin between refined product prices and the prices for crude oil and other feedstocks. When the margin between refined product prices and crude oil and other feedstock prices contracts or inverts, as has been the case in recent periods and may continue to be the case in the future, our results of operations and cash flows are negatively affected. Refining margins historically have been volatile, and are likely to continue to be volatile as a result of a variety of factors including fluctuations in the prices of crude oil, other feedstocks, refined products and fuel and utility services. The direction and timing of changes in prices for crude oil and refined products do not necessarily correlate with one another and it is the relationship between such prices, rather than the nominal amounts of such prices, that has the greatest impact on our results of operations and cash flows.

Prices of crude oil, other feedstocks and refined products, and the relationships between such prices and prices for refined products, depend on numerous factors beyond our control, including the supply of and demand for crude oil, other feedstocks, gasoline, diesel and other refined products and the relative magnitude and timing of such changes. Such supply and demand are affected by, among other things:

• changes in general economic conditions;

• changes in the underlying demand for our products;

• the availability, costs and price volatility of crude oil, other refinery feedstocks and refined products;

• worldwide political conditions, particularly in significant oil producing regions such as the Middle East, West Africa and Latin America;

• the level of foreign and domestic production of crude oil and refined products and the volume of crude oil, feedstock and refined products imported into and exported from the United States;

• refinery utilization rates;

• the development and marketing of alternative and competing fuels;

• the effects of transactions involving forward contracts and derivative instruments and general commodities speculation;

• infrastructure limitations;

• accidents, interruptions in transportation, inclement weather or other events that can cause unscheduled shutdowns or otherwise adversely affect refineries;

• the effects of and cost of compliance with current and future state and federal environmental, economic, safety and other laws, policies and regulations; and

• local factors, including market conditions, weather conditions and the level of operations of other refineries and pipelines in our market.

Although we continually analyze our operating margins and seek to adjust throughput volumes and product slates to optimize our operating results based on market conditions, there are inherent limitations on our ability to offset the effects of adverse market conditions. For example, reductions in throughput volumes in a negative operating margin environment may reduce operating losses, but it would not eliminate them because we would still be incurring fixed costs and other variable costs.

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The price volatility of crude oil and refined products will affect the market value of our inventories, which could have a material adverse effect on our earnings, profitability and cash flows.

The nature of our business has historically required 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. Our inventory is valued at the lower of cost or market value under the last-in, first-out ("LIFO") inventory valuation methodology. As a result, if the market value of our inventory were to decline to an amount less than our LIFO cost, we would record a write-down of inventory and a non-cash charge to cost of sales.

The price volatility of fuel and utility services may have a material adverse effect on our earnings, profitability and cash flows.

The volatility in costs of natural gas, electricity and other utility services used by our refinery affect our operating costs. Utility prices have been, and will continue to be, affected by factors outside our control, such as supply and demand for utility services in both local and regional markets. Future increases in utility prices may have a negative effect on our earnings, profitability and cash flows.

The recent recession and credit crisis and related turmoil in the global financial system has had and may continue to have an adverse impact on our business, results of operations and cash flows.

Our business and profitability are affected by the overall level of demand for our products, which in turn is affected by factors such as overall levels of economic activity and business and consumer confidence and spending. Recent declines in global economic activity and consumer and business confidence and spending have significantly reduced the level of demand for our products. In addition, severe reductions in the availability and increases in the cost of credit have adversely affected our ability to fund our operations and operate our refinery at full capacity, and have adversely affected our operating margins. Together, these factors have had and may continue to have an adverse impact on our business, financial condition, results of operations and cash flows.

Our business is indirectly exposed to risks faced by our suppliers, customers and other business partners. The impact on these constituencies of the risks posed by the recent recession and credit crisis and related turmoil in the global financial system have included or could include interruptions or delays in the performance by counterparties to our contracts, reductions and delays in customer purchases, delays in or the inability of customers to obtain financing to purchase our products and the inability of customers to pay for our products. Any of these events may have an adverse impact on our business, financial condition, results of operations and cash flows.

The dangers inherent in our operations could cause disruptions and could expose us to potentially significant losses, costs or liabilities. We are particularly vulnerable to disruptions in our operations because all of our refining operations are conducted at a single facility.

Our operations are subject to significant hazards and risks inherent in refining operations and in transporting and storing crude oil, intermediate products and refined products. These hazards and risks include, but are not limited to, natural disasters, fires, explosions, pipeline ruptures and spills, third party interference and mechanical failure of equipment at our or third-party facilities, any of which could result in production and distribution difficulties and disruptions, environmental pollution, personal injury or wrongful death claims and other damage to our properties and the property of others.

There is also risk of mechanical failure and equipment shutdowns both in general and following unforeseen events. In such situations, undamaged refinery processing units may be dependent on or interact with damaged process units and, accordingly, are also subject to being shutdown.

Because all of our refining operations are conducted at a single refinery, any of such events at our refinery could significantly disrupt our production and distribution of refined products, and any sustained disruption could have a material adverse effect on our business, financial condition, results of operations and cash flows.

We are subject to interruptions of supply and distribution as a result of our reliance on pipelines and barges for transportation of crude oil and refined products.

Our refinery receives a substantial percentage of crude oil and delivers a substantial percentage of refined products through pipelines and barges. We could experience an interruption of supply or delivery, or an increased cost of receiving crude oil and delivering refined products to market, if the ability of these pipelines and barges to transport crude oil or refined products is disrupted because of accidents, earthquakes, hurricanes, flooding, governmental regulation, terrorism, other third party action or any of the types of events described in the preceding risk factor. Our prolonged inability to use any of the pipelines and

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barges that we use to transport crude oil or refined products could have a material adverse effect on our business, results of operations and cash flows.

Commodity derivative contracts may limit our potential gains, exacerbate potential losses, result in period-to-period earnings volatility and involve other risks.

We may enter into commodity derivatives contracts to mitigate our crack spread risk with respect to a portion of our expected gasoline and diesel production. We enter into these arrangements with the intent to secure a minimum fixed cash flow stream on the volume of products hedged during the hedge term. However, our hedging arrangements may fail to fully achieve these objectives for a variety of reasons, including our failure to have adequate hedging contracts, if any, in effect at any particular time and the failure of our hedging arrangements to produce the anticipated results. We may not be able to procure adequate hedging arrangements due to a variety of factors. Moreover, while intended to reduce the adverse effects of fluctuations in crude oil and refined product prices, such transactions may limit our ability to benefit from favorable changes in margins. In addition, our hedging activities may expose us to the risk of financial loss in certain circumstances, including instances in which:

• the volumes of our actual use of crude oil or production of the applicable refined products is less than the volumes subject to the hedging arrangement;

• accidents, interruptions in feedstock transportation, inclement weather or other events cause unscheduled shutdowns or otherwise adversely affect our refinery, or those of our suppliers or customers;

• the counterparties to our futures contracts fail to perform under the contracts; or

• a sudden, unexpected event materially impacts the commodity or crack spread subject to the hedging arrangement.

As a result, the effectiveness of our risk mitigation strategy could have a material adverse impact on our financial results and our ability to make distributions. See “Management’s Discussion and Analysis of Financial Condition and Results of Operations—Quantitative and Qualitative Disclosures About Market Risk.”

Changes in our credit profile could affect our relationships with our suppliers, which could have a material adverse effect on our liquidity and our ability to operate our refinery at full capacity.

Changes in our credit profile could affect the way crude oil suppliers view our ability to make payments and induce them to shorten the payment terms for our purchases or require us to post security prior to payment. Due to the large dollar amounts and volume of our crude oil and other feedstock purchases, any imposition by our suppliers of more burdensome payment terms on us may have a material adverse effect on our liquidity and our ability to make payments to our suppliers. This, in turn, could cause us to be unable to operate our refinery at full capacity. A failure to operate our refinery at full capacity could adversely affect our profitability and cash flows.

Our arrangement with J. Aron exposes us to J. Aron related credit and performance risk.

We have a supply and offtake agreement with J. Aron, who is our largest supplier of crude oil and largest customer of refined products. In the future, we could purchase up to 100% of our supply needs from J. Aron pursuant to this agreement. Additionally, we are obligated to repurchase all consigned inventories and certain other inventories upon termination of this agreement, which may be terminated by J. Aron as early as May 31, 2016. Relying on J. Aron’s ability to honor its fuel requirements purchase obligations exposes us to J. Aron’s credit and business risks. An adverse change in J. Aron’s business, results of operations, liquidity or financial condition could adversely affect its ability to perform its obligations, which could consequently have a material adverse effect on our business, results of operations or liquidity. In addition, we may be required to use substantial capital to repurchase inventories from J. Aron upon termination of the agreement, which could have a material adverse effect on our financial condition.

Competition in the refining and marketing industry is intense, and an increase in competition in the markets in which we sell our products could adversely affect our earnings and profitability.

We compete with a broad range of companies in our refining and marketing operations. Many of these competitors are integrated, multinational oil companies that are substantially larger than we are. Because of their diversity, integration of operations, larger capitalization, larger and more complex refineries and greater resources, these companies may be better able to withstand disruptions in operations and volatile market conditions, to offer more competitive pricing and to obtain crude oil in times of shortage.

We are not engaged in the exploration and production business and therefore do not produce any of our crude oil feedstocks. Certain of our competitors, however, obtain a portion of their feedstocks from company-owned production.

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Competitors that have their own crude production are at times able to offset losses from refining operations with profits from producing operations, and may be better positioned to withstand periods of depressed refining margins or feedstock shortages. In addition, we compete with other industries, such as wind, solar and hydropower, which provide alternative means to satisfy the energy and fuel requirements of our industrial, commercial and individual customers. If we are unable to compete effectively with these competitors, both within and outside our industry, there could be a material adverse effect on our business, financial condition, results of operations and cash flows.

We may incur significant costs to comply with new or changing environmental laws and regulations.

Our operations are subject to extensive regulatory controls on air emissions, water discharges, waste management and the clean-up of contamination that can require costly compliance measures. If we fail to meet environmental requirements, we may be subject to administrative, civil and criminal proceedings by state and federal authorities, as well as civil proceedings by environmental groups and other individuals, which could result in substantial fines and penalties against us as well as governmental or court orders that could alter, limit or stop our operations.

The U.S. House of Representatives and the U.S. Senate are in various stages of considering legislation intended to control and reduce emissions of "greenhouse gases," or "GHGs," in the United States. GHGs are certain gases, including carbon dioxide and methane, which may be contributing to warming of the Earth's atmosphere and other climatic changes.

Although it is not possible at this time to predict when the House and Senate may enact climate change legislation, any laws or regulations that may be adopted to restrict or reduce emissions of GHGs would likely require us to incur increased costs. If we are unable to sell our refined products at a price that reflects such increased costs, there could be a material adverse effect on our business, financial condition and results of operations. In addition, any increase in prices of refined products resulting from such increased costs could have an adverse effect on our financial condition, results of operations and cash flows.

In addition to the climate change legislation under consideration by Congress, on December 7, 2009, the EPA issued an endangerment finding that GHGs endanger both public health and welfare, and that GHG emissions from motor vehicles contribute to the threat of climate change. Although the finding itself does not impose requirements on regulated entities, it allowed the EPA and the Department of Transportation to finalize a jointly proposed rule regulating greenhouse gas emissions from vehicles and establishing Corporate Average Fuel Economy standards for light-duty vehicles. National GHG tailpipe standards for passenger cars and light trucks were finalized on April 1, 2010.

Once GHGs became regulated by the EPA for vehicles, they also became regulated pollutants under the Clean Air Act potentially triggering other Clean Air Act requirements. On May 13, 2010, EPA announced a final rule to raise the threshold amount of GHG emissions that a source would have to emit to trigger certain Clean Air Act permitting requirements and the need to install controls to reduce emissions of greenhouse gases. Beginning in January 2011, facilities already subject to the Prevention of Significant Deterioration and Title V operating permit programs that increase their emissions of GHGs by 75,000 tons per year will be required to install control technology, known as "Best Available Control Technology," to address the GHG emissions. Both the endangerment finding and stationary source rule are being challenged, however. If the EPA's actions withstand legal challenge, the new obligations finalized in the stationary source rule could require us to incur increased costs. If we are unable to sell our refined products at a price that captures such increased costs, there could be a material adverse effect on our business, financial condition and results of operations. In addition, any increase in prices of refined products resulting from such increased costs could have an adverse effect on our financial condition, results of operations and cash flows.

In addition, new laws and regulations, new interpretations of existing laws and regulations, increased governmental enforcement or other developments could require us to make additional unforeseen expenditures. Many of these laws and regulations are becoming increasingly stringent, and the cost of compliance with these requirements can be expected to increase over time. We are not able to predict the impact of new or changed laws or regulations or changes in the ways that such laws or regulations are administered, interpreted or enforced. The requirements to be met, as well as the technology and length of time available to meet those requirements, continue to develop and change. To the extent that the costs associated with meeting any of these requirements are substantial and not adequately provided for, our results of operations and cash flows could suffer.

We may incur significant costs and liabilities with respect to environmental lawsuits and proceedings and any investigation and remediation of existing and future environmental conditions.

In connection with the acquisition of our refinery from Valero, we became party to an agreement that allocated the parties' respective obligations under the Valero global settlement consent decree. The parties are in discussions regarding the appropriate levels of NOx emissions for the refinery's catalytic cracking unit, which is part of a Valero system-wide NOx emissions limit in the consent decree. Depending on the outcome of these discussions, it may be necessary for us to install additional controls or take other steps to reduce emissions of NOx from the catalytic cracking unit.

8

We could incur substantial costs or disruptions in our business if we cannot obtain or maintain necessary permits and authorizations or otherwise comply with health, safety, environmental and other laws and regulations.

From time to time, we have been sued or investigated for alleged violations of health, safety, environmental and other laws. If a lawsuit or enforcement proceeding were commenced or resolved against us, we could incur significant costs and liabilities. In addition, our operations require numerous permits and authorizations under various laws and regulations. These authorizations and permits are subject to revocation, renewal or modification and can require operational changes to limit impacts or potential impacts on the environment and/or health and safety. A violation of authorization or permit conditions or other legal or regulatory requirements could result in substantial fines, criminal sanctions, permit revocations, injunctions, and/or facility shutdowns. In addition, major modifications of our operations could require modifications to our existing permits or upgrades to our existing pollution control equipment. Any or all of these matters could have a negative effect on our business, results of operations, cash flows or prospects.

We are located in an area that has a history of hurricanes and flooding, the occurrence of which could materially affect our operations.

From mid-May to mid-June 2011, our refinery was shutdown in anticipation of potential flooding from the opening of the Morganza Spillway, which diverted water from the Mississippi River to the Atchafalaya Basin and the Atchafalaya River. Our refinery did not incur any damage; however, this flooding did impact crude supply to our refinery.

In August 2008, our refinery sustained minor physical damage from Hurricane Gustav; however, the regional utilities were affected and, as a result, our refinery was without electric power for one week. Offshore crude oil production and gathering facilities were impacted by Gustav and a subsequent storm, which temporarily limited the availability of crude oil to our refinery. In the event hurricanes or floods cause damage to our refinery, or the infrastructure necessary for the operation of the refinery, such as the availability of usable roads, electricity, water, or natural gas, we may experience a significant interruption in our refining operations. Such an interruption could have a material adverse effect on our business, results of operations and cash flows.

Terrorist attacks, threats of war or actual war may negatively affect our operations, financial condition, results of operations and prospects.

Terrorist attacks, threats of war or actual war, as well as events occurring in response to or in connection with them, may adversely affect our operations, financial condition, results of operations and prospects. Energy-related assets (such as our refinery) may be at greater risk of terrorist attacks than other possible targets in the United States. A direct attack on our assets or assets used by us could have a material adverse effect on our operations, financial condition, results of operations and prospects. In addition, any terrorist attack, threats of war or actual war could have an adverse impact on energy prices, including prices for our crude oil and refined products, and an adverse impact on refining margins. In addition, disruption or significant increases in energy prices could result in government-imposed price controls.

Our insurance policies do not cover all losses, costs or liabilities that we may experience.

We maintain significant insurance coverage, but it does not cover all potential losses, costs or liabilities, and our business interruption insurance coverage does not apply unless a business interruption exceeds a period of 45 days. We could suffer losses for uninsurable or uninsured risks or in amounts in excess of our existing insurance coverage. Our ability to obtain and maintain adequate insurance may be affected by conditions in the insurance market over which we have no control. The occurrence of an event that is not fully covered by insurance could have a material adverse effect on our business, financial condition and results of operations.

If we lose any of our key personnel, our ability to manage our business and continue our growth could be negatively affected.

Our future performance depends to a significant degree upon the continued contributions of our senior management team and key technical personnel, most of who are employed by an affiliate of our corporate parent, Alon USA. We do not currently maintain key man life insurance with respect to any member of our senior management team. The loss or unavailability to us of any member of our senior management team or a key technical employee could significantly harm us. We face competition for these professionals from our competitors, our customers and other companies operating in our industry. To the extent that the services of members of our senior management team and key technical personnel would be unavailable to us for any reason, we would need to hire other personnel to manage and operate our refinery and to develop our products and technology. We cannot assure you that we would be able to locate or employ qualified personnel on acceptable terms or at all. To the extent members of our senior management team are performing services for Alon USA, this may divert their time and attention away from our business and may therefore adversely affect our business. In addition, we cannot assure you that the interests of our parent company will always be aligned with the interests of our company or the holders of our senior secured notes.

9

Risk Factors Relating to Outstanding Indebtedness and Debt Agreements

Our substantial level of indebtedness could adversely affect our financial condition and prevent us from fulfilling our obligations under our senior secured notes.

Subject to restrictions in the Indenture governing our Senior Secured Notes, we may incur additional indebtedness. Our indebtedness could have important consequences to you and significant effects on our business, including the following:

• it may be more difficult for us to satisfy our financial obligations, including with respect to our Senior Secured Notes;

• our ability to obtain additional financing for working capital, capital expenditures or general corporate purposes may be impaired;

• we must use a substantial portion of our cash flow from operations to pay interest on our Senior Secured Notes as well as to fund excess cash flow;

• offers on our Senior Secured Notes, which will reduce the funds available to use for operations and other purposes;

• our ability to fund a change of control offer may be limited;

• our ability to borrow additional funds may be limited;

• our indebtedness could place us at a competitive disadvantage compared to those of our competitors that may have proportionately less debt;

• our flexibility in planning for, or reacting to, changes in our business and the industry in which we operate may be limited;

• we may be restricted from making strategic acquisitions or exploiting other business opportunities; and

• our level of indebtedness makes us more vulnerable to economic downturns and adverse developments in our business.

We expect to use cash flow from operations to pay our expenses and scheduled interest and principal payments due under our Senior Secured Notes. Our ability to make these payments thus depends on our future performance, which is affected by financial, business, economic and other factors, many of which we cannot control. The recent recession and credit crisis and related turmoil in the global financial system has had and may continue to have an adverse effect on our business, financial condition, results of operations and cash flows. Consequently, our business may not generate sufficient cash flow from operations in the future and our anticipated growth in revenue and cash flow may not be realized, either or both of which could result in our being unable to repay or pay interest on our Senior Secured Notes, or to fund other liquidity needs. If we do not have enough money, we may be required to refinance all or part of our Senior Secured Notes, sell assets or borrow more money. We cannot make any assurances that we will be able to accomplish any of these alternatives on terms acceptable to us, or at all. In addition, the terms of the Indenture governing our Senior Secured Notes, may restrict us from adopting any of these alternatives. The failure to generate sufficient cash flow or to achieve any of these alternatives could significantly adversely affect the value of our Senior Secured Notes and our ability to pay the amounts due under our Senior Secured Notes. In addition, if we default in the payment of amounts due on our Senior Secured Notes, it would give rise to an event of default under the Indenture governing our Senior Secured Notes. In the event of any acceleration, there can be no assurance that we will have enough cash to repay our outstanding Senior Secured Notes.

Despite our current indebtedness level, we may still be able to incur substantially more debt, which could exacerbate the risks associated with our substantial leverage.

We may be able to incur substantial additional indebtedness in the future. The terms of the Indenture governing our Senior Secured Notes do not fully prohibit us from doing so. If new debt is added to our current debt levels, the related risks that we now face could intensify.

Our Indenture governing our Senior Secured Notes imposes significant operating and financial restrictions, which may prevent us from pursuing certain business opportunities and taking certain actions.

Our Indenture governing our Senior Secured Notes imposes, and future debt agreements may impose, significant operating and financial restrictions on us.

These restrictions limit or prohibit, among other things, our ability to:

• incur additional indebtedness;

• repay our Senior Secured Notes prior to stated maturities;

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• make acquisitions or investments;

• create or incur liens;

• transfer or sell certain assets or merge or consolidate with or into other companies;

• enter into certain transactions with affiliates; and

• otherwise conduct certain corporate activities.

These restrictions could adversely affect our ability to finance our future operations or capital needs and pursue available business opportunities. A breach of any of these restrictions could result in a default in respect to our Senior Secured Notes.

ITEM 1B. UNRESOLVED STAFF COMMENTS.

None.

ITEM 3. LEGAL PROCEEDINGS.

In the ordinary conduct of our business, we are subject to periodic lawsuits, investigations and claims, including environmental claims and employee related matters. Although we cannot predict with certainty the ultimate resolution of lawsuits, investigations and claims asserted against us, we do not believe that any currently pending legal proceeding or proceedings to which we are a party will have a material adverse effect on our business, results of operations, cash flows or financial condition.

ITEM 4. MINE SAFETY DISCLOSURES.

None.

11

PART II

ITEM 5. MARKET FOR REGISTRANT'S COMMON EQUITY, RELATED STOCKHOLDER MATTERS ANDISSUER PURCHASES OF EQUITY SECURITIES.

As of March 1, 2013, Alon USA is the only holder of all of the Company's outstanding voting capital stock. There is no established public trading market for the Company's common stock. We did not declare or pay dividends on our capital stock in 2012 or 2011. Our debt agreements contain provisions that limit our ability to pay dividends.

ITEM 6. SELECTED FINANCIAL DATA.

Omitted under the reduced disclosure format permitted by General Instruction I(2)(a) of Form 10-K.

ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

The following discussion of our financial condition and results ofoperations is provided as a supplement to, and should be read in conjunctionwith, our financial statements and the notes thereto includedelsewhere in this Annual Report on Form 10-K and the other sections of thisAnnual Report on Form 10-K, including Items 1 and 2 “Business and Properties.”

For additional information, including information regarding outlook, liquidity, capital resources, contractual obligations, and critical accounting estimates, see the Annual Report on Form 10-K of our parent, Alon USA Energy, Inc., for the year ended December 31, 2012.

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. See Item 1A "Risk Factors."

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:

• 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 spread between West Texas Intermediate crude oil and Light Louisiana Sweet crude oil;

• the effects of transactions involving forward contracts and derivative instruments;

• actions of customers and competitors;

• termination of our Supply and Offtake Agreement with J. Aron & Company (“J. Aron”), under which J. Aron is our largest supplier of crude oil and our largest customer of refined products. Additionally, we are obligated to repurchase all consigned inventories and certain other inventories upon termination of the Supply and Offtake Agreement;

• 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 and cost of compliance with current and future state and federal environmental, economic, safety and other laws, policies and regulations;

• operating hazards, natural disasters such as flooding, casualty losses and other matters beyond our control; and

• the other factors discussed in this Annual Report on Form 10-K 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.

Major Influences on Results of Operations

Our earnings and cash flows 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 depends on numerous factors beyond our control, including the supply of, and demand for, crude oil, gasoline and other refined products which, in turn, depends 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, which affects our earnings.

In order to measure our operating performance, we compare our per barrel refinery operating margins to certain industry benchmarks. We compare our refinery’s per barrel operating margin to the Gulf Coast 2/1/1 crack spread. The Gulf Coast 2/1/1 crack spread is calculated assuming that two barrels of a benchmark crude oil are converted, or cracked, into one barrel of gasoline and one barrel of diesel. We calculate the Gulf Coast 2/1/1 crack spread using the market values of Gulf Coast conventional gasoline and Gulf Coast high sulfur diesel and the market value of Light Louisiana Sweet, or LLS, crude oil.

Our refinery has the capability to process substantial volumes of low-sulfur, or sweet, crude oils to produce a high percentage of light, high-value refined products. Sweet crude oil typically comprises 100% of our refinery’s crude oil input. This input is primarily comprised of LLS crude oil and WTI crude oil. We measure the cost of refining the LLS crude oil by calculating the difference between the average value of LLS crude oil and the average value of WTI crude oil. A narrowing of this spread can favorably influence the refinery operating margins.

Our results of operations are also significantly affected by our refinery’s operating costs, particularly the cost of natural gas used for fuel and the cost of electricity. Natural gas prices have historically been volatile. Typically, electricity prices fluctuate with natural gas prices.

Factors Affecting Comparability

Our financial condition and operating result over the three-year period ended December 31, 2012 have been influenced by the following factors which are fundamental to understanding comparisons of our period-to-period financial performance.

Certain Derivative Impacts

We had (gains) losses on commodity swaps of $116.0 million and $(30.0) million for the years ended December 31, 2012 and 2011, respectively.

Included in other loss, net in the statements of operations, we had losses on heating oil call option crack spread contracts of $7.3 million, $36.3 million and $4.1 million for the years ended December 31, 2012, 2011 and 2010, respectively.

Unscheduled Turnaround and Reduced Crude Oil Throughput

In an effort to match our safety, reliability and the environmental performance initiatives with the current operating margin environment, we accelerated a planned turnaround at our refinery from the first quarter of 2010 to the fourth quarter of 2009. The refinery resumed operations in June 2010. Crude throughput was reduced at our refinery during the second quarter of 2011 due to the flooding in Louisiana and its impact on crude oil supply to the refinery.

13

ALON REFINING KROTZ SPRINGS, INC.

Summary Financial Tables. The following table provides summary financial data and selected key operating statistics for the years endedDecember 31, 2012, 2011 and 2010. The following data should be read in conjunction with our financial statements and the notes thereto included elsewhere in this Annual Report on Form 10-K.

	Year Ended December 31,
	2012			2011			2010
	(dollars in thousands)
STATEMENT OF OPERATIONS DATA:
Net sales	$	2,881,242		$	2,533,092		$	1,254,663
Operating costs and expenses:
Cost of sales	2,674,978			2,463,950			1,218,347
(Gains) losses on commodity swaps	116,020			(30,040		)	7,837
Direct operating expenses	95,713			79,972			62,321
Selling, general and administrative expenses	7,828			6,827			6,890
Depreciation and amortization	23,882			22,645			21,844
Total operating costs and expenses	2,918,421			2,543,354			1,317,239
Loss on disposition of assets	(2,504		)	—			—
Operating loss	(39,683		)	(10,262		)	(62,576		)
Interest expense (1)	(44,417		)	(40,977		)	(47,695		)
Other loss, net (2)	(7,289		)	(36,232		)	(4,105		)
Loss before income tax benefit	(91,389		)	(87,471		)	(114,376		)
Income tax benefit	—			—			—
Net loss	$	(91,389	)	$	(87,471	)	$	(114,376	)
KEY OPERATING STATISTICS:
Per barrel of throughput:
Refinery operating margin (3)	$	8.30		$	3.05		$	2.24
Refinery direct operating expense (4)	3.85			3.67			4.36
Capital expenditures	$	17,023		$	18,909		$	7,350
Capital expenditures for turnaround and chemical catalyst	1,163			2,649			2,383
PRICING STATISTICS:
WTI crude oil (per barrel)	$	94.14		$	95.07		$	79.41
LLS crude oil (per barrel)	111.53			110.98			80.61
Crude oil differentials (per barrel):
LLS less WTI	$	16.46		$	16.76		$	2.49
Product price (dollars per gallon):
Gulf Coast unleaded gasoline	$	2.82		$	2.75		$	2.05
Gulf Coast high sulfur diesel	2.99			2.91			2.10
Natural gas (per MMBTU)	2.83			4.03			4.38
Crack spreads (2/1/1) (per barrel):
Gulf Coast high sulfur diesel	$	11.29		$	7.00		$	5.26

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	Year Ended December 31,
	2012			2011			2010
THROUGHPUT AND PRODUCTION DATA:	bpd	%		bpd	%		bpd	%
Refinery throughput:
WTI crude	20,111	29.6		—	—		—	—
Gulf Coast sweet crude	46,924	69.2		58,979	98.8		38,345	97.7
Blendstocks	842	1.2		741	1.2		899	2.3
Total refinery throughput (5)	67,877	100.0		59,720	100.0		39,244	100.0
Refinery production:
Gasoline	29,081	42.4		24,852	41.4		15,812	40.1
Diesel/jet	28,466	41.4		27,436	45.6		18,986	48.2
Heavy Oils	2,709	3.9		2,904	4.8		1,515	3.8
Other	8,464	12.3		4,914	8.2		3,107	7.9
Total refinery production (6)	68,720	100.0		60,106	100.0		39,420	100.0
Refinery utilization (7)		80.7	%		77.9	%		46.1	%

(1) Interest expense for the year ended December 31, 2010, includes a charge of $6,659 for the write-off of debt issuance costs associated with our prepayment of the revolving credit facility.

(2) Other loss, net for the years ended December 31, 2012, 2011 and 2010 is substantially the loss on heating oil call option crack spread contracts.

(3) Refinery operating margin is a per barrel measurement calculated by dividing the margin between net sales and cost of sales (exclusive of substantial hedge positions and certain inventory adjustments) by the refinery’s throughput volumes. Industry-wide refining results are driven 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 margin to these crack spreads to assess our operating performance relative to other participants in our industry.

The refinery operating margin for the year ended December 31, 2011 excludes hedge gains of $2,702.

The refinery operating margin for the year ended December 31, 2010 excludes an unrealized loss associated with consignment inventory of $3,537 and includes losses on commodity swaps of $7,837.

(4) Refinery direct operating expense is a per barrel measurement calculated by dividing direct operating expenses at the refinery by the refinery’s total throughput volume.

(5) Total refinery throughput represents the total barrels per day of crude oil and blendstock inputs in the refinery production process. See previous discussion in "Factors Affecting Comparability" for more information regarding throughput.

(6) Total refinery production represents the barrels per day of various products produced from processing crude and other refinery feedstocks through the crude unit and other conversion units at the refinery.

(7) 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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Year Ended December 31, 2012 Compared to the Year Ended December 31, 2011

Net Sales. Net sales for the year ended December 31, 2012, were $2,881.2 million, compared to $2,533.1 million for the year ended December 31, 2011, an increase of $348.1 million. The increase was due to higher refined product prices and higher refinery throughput in the year ended December 31, 2012 compared to last year. Refinery throughput for the the year ended December 31, 2012 was 67,877 barrels per day, compared to 59,720 barrels per day for the year ended December 31, 2011, where throughput was reduced in 2011 due to flooding in Louisiana and the impact on crude oil supply to the refinery. The average price of Gulf Coast gasoline for the year ended December 31, 2012 increased $0.07, or 2.5%, to $2.82, compared to $2.75 for the year ended December 31, 2011. The average per gallon price for Gulf Coast high sulfur diesel for the year ended December 31, 2012, increased $0.08, or 2.7%, to $2.99, compared to $2.91 for the year ended December 31, 2011.

Cost of Sales. Cost of sales for the year ended December 31, 2012, were $2,675.0 million compared to $2,464.0 million for the year ended December 31, 2011, an increase of $211.0 million. This increase was primarily due to increased refinery throughput as a result of the factors discussed previously as well as an increase in the cost of crude oil used by our refinery. The average price per barrel of LLS for the year ended December 31, 2012, increased $0.55 per barrel, or 0.5%, to an average of $111.53 per barrel, compared to an average of $110.98 per barrel for the year ended December 31, 2011.

Direct Operating Expenses. Direct operating expenses were $95.7 million for the year ended December 31, 2012, compared to $80.0 million for the year ended December 31, 2011, an increase of $15.7 million, or 19.6%. The increase in direct operating expenses for the year ended December 31, 2012 is due primarily to increased refinery throughput.

Operating Loss. Operating loss for the year ended December 31, 2012, was $39.7 million, compared to $10.3 million for the year ended December 31, 2011, an increase in loss of $29.4 million. The increase in loss was due to losses on commodity swaps of $116.0 million for the year ended December 31, 2012 compared to gains on commodity swaps of $30.0 million for the year ended December 31, 2011. These losses were partially offset by higher refinery throughput and higher refinery margins for the year ended December 31, 2012. The refinery margin for the year ended December 31, 2012 was $8.30 per barrel compared to $3.05 per barrel for the year ended December 31, 2011. This increase is primarily due to lower crude oil costs with the addition of WTI priced crude oils and higher Gulf Coast 2/1/1 high sulfur diesel crack spreads. The average Gulf Coast 2/1/1 high sulfur diesel crack spread for the year ended December 31, 2012 was $11.29 per barrel compared to $7.00 per barrel for the year ended December 31, 2011.

Interest Expense. Interest expense was $44.4 million for the year ended December 31, 2012, compared to $41.0 million for the year ended December 31, 2011, an increase of $3.4 million, or 8.3%. The increase was due primarily to increased interest on letters of credit and finance charges in the year ended December 31, 2012.

Other Loss, Net. Other loss, net for the years ended December 31, 2012 and 2011 is substantially the loss on heating oil call option crack spread contracts.

Net Loss. Net loss was $91.4 million for the year ended December 31, 2012, compared to $87.5 million for the year ended December 31, 2011, an increase in loss of $3.9 million or 4.5%. This increase in loss was attributable to the factors discussed above.

Liquidity and Capital Resources

Our primary sources of liquidity are cash generated from our operating activities, inventory supply and offtake arrangements, credit lines and additional funding from Alon USA. Future operating results will depend on market factors, primarily the difference between the prices we receive from customers for produced products compared to the prices we pay to suppliers for crude oil. We plan to continue to operate the refinery at current or higher utilization rates as long as the refinery is able to generate cash operating margin. Management believes its current liquidity from the above-described sources is adequate to operate the refinery.

Critical Accounting Policies

Our accounting policies are described in the notes to our audited financial statements included elsewhere in this Annual Report on Form 10-K. We prepare our 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, which are discussed below, could materially affect the amounts recorded in our financial statements.

Inventory. Crude oil, refined products and blendstocks are priced at the lower of cost or market value. Cost is determined using the LIFO valuation method. Under the LIFO valuation method, we charge the most recent acquisition costs to cost of sales, and we value inventories at the earliest acquisition costs. We selected this method because we believe it more accurately

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reflects the cost of our current sales. If the market value of inventory is less than the inventory cost on a LIFO basis, then the inventory is written down to market value. An inventory write-down to market value results in a non-cash accounting adjustment, decreasing the value of our crude oil and refined products inventory and increasing our cost of sales. Market values of crude oil, refined products and blendstocks exceeded LIFO costs by $14.0 million and $18.4 million at December 31, 2012 and 2011, respectively.

Environmental and Other Loss Contingencies. We record liabilities for loss contingencies, including environmental remediation costs, when such losses are probable and can be reasonably estimated. Our environmental liabilities represent the estimated cost to investigate and remediate contamination at our properties. Our estimates are based upon internal and third-party assessments of contamination, available remediation technology and environmental regulations. Accruals for estimated liabilities from projected environmental remediation obligations are recognized no later than the completion of the remedial feasibility study. These accruals are adjusted as further information develops or circumstances change. We do not discount environmental liabilities to their present value unless payments are fixed and determinable. We record them without considering potential recoveries from third parties. Recoveries of environmental remediation costs from third parties are recorded as assets when receipt is deemed probable. We update our estimates to reflect changes in factual information, available technology or applicable laws and regulations.

Turnarounds and Chemical Catalyst Costs. We record the cost of planned major refinery maintenance, referred to as turnarounds, and chemical catalyst used in the refinery process units, which are typically replaced in conjunction with planned turnarounds, in “Other assets” in our financial statements. Turnaround and catalyst costs are currently deferred and amortized on a straight-line basis beginning the month after the completion of the turnaround and ending immediately prior to the next scheduled turnaround. The amortization of deferred turnaround and chemical catalysts costs are presented in “Depreciation and amortization” in our financial statements.

Impairment of Long-Lived Assets. We account for impairment of long-lived assets in accordance with Financial Accounting Standards Board (“FASB”) Accounting Standards Codification (“ASC”) Subtopic 360-10, Property, Plant, and Equipment. In evaluating our assets, long-lived assets and certain identifiable intangible assets are reviewed for impairment whenever events or changes in circumstances indicate that the carrying amount of such assets may not be recoverable. Recoverability of assets to be held and used is measured by a comparison of the carrying value of an asset to future net cash flows expected to be generated by the asset. If the carrying value of an asset exceeds its expected future cash flows, an impairment loss is recognized based on the excess of the carrying value of the impaired asset over its fair value. These future cash flows and fair values are estimates based on our judgment and assumptions. Assets to be disposed of are reported at the lower of the carrying amount or fair value less costs of disposition.

Deferred Income Taxes. Income taxes are accounted for under the asset and liability method. Deferred tax assets and liabilities are recognized for the future tax consequences attributable to differences between the financial statement carrying amounts of existing assets and liabilities and their respective tax bases and operating loss and tax credit carryforwards. Deferred tax assets and liabilities are measured using enacted tax rates expected to apply to taxable income in the years in which those temporary differences are expected to be recovered or settled. The effect on deferred tax assets and liabilities of a change in tax rates is recognized in income in the period that includes the enactment date. Our results of operations are included in the consolidated U.S. Federal income tax return of Alon USA. For financial reporting purposes, federal tax expense is allocated to us as if a separate return was filed.

Asset Retirement Obligations. We use ASC Subtopic 410-20, Asset Retirement Obligations, which established accounting standards for recognition and measurement of a liability for an asset retirement obligation and the associated asset retirement costs. The provisions of ASC Subtopic 410-20 apply to legal obligations associated with the retirement of long-lived assets that result from the acquisition, construction, development and/or normal operation of a long-lived asset. ASC Subtopic 410-20 also requires companies to recognize a liability for the fair value of a legal obligation to perform asset retirement activities that are conditional on a future event, if the amount can be reasonably estimated.

In order to determine fair value, management must make certain estimates and assumptions including, among other things, projected cash flows, a credit-adjusted risk-free rate and an assessment of market conditions that could significantly impact the estimated fair value of the asset retirement obligation. These estimates and assumptions are subjective.

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ITEM 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK.

Changes in commodity prices and purchased fuel prices are our primary sources of market risk. Alon USA's 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. Alon USA's 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 Alon USA's risk management committee, we may utilize the commodity futures market to manage these anticipated inventory variances. In addition, we have entered into and regularly evaluate opportunities to provide us with a minimum fixed cash flow stream on the volume of products hedged during the hedge term and to protect against volatility on commodity prices.

We maintain inventories of crude oil, refined products and blendstocks, 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 December 31, 2012, we held approximately 0.5 million barrels of crude oil and product inventories valued under the LIFO valuation method. Market value exceeded carrying value of LIFO costs by $14.0 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 $0.5 million.

In accordance with ASC 815-10, 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 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.

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The following table provides information about our derivative commodity instruments as of December 31, 2012:

Description of Activity	Contract Volume (in barrels)		Wtd Avg Purchase Price/BBL		Wtd Avg Sales Price/BBL		Contract Value			Fair Value			Gain (Loss)
							(in thousands)
Forwards-long (Crude)	505,070		92.40		—		$	46,666		$	48,472		$	1,806
Forwards-short (Distillate)	(76,791	)	—		120.89		(9,283		)	(9,397		)	(114		)
Forwards-long (Gasoline)	78,273		108.24		—		8,472			8,850			377
Forwards-long (Jet)	39,249		123.51		—		4,848			4,952			105
Forwards-short (Jet)	(50,000	)	—		126.04		(6,302		)	(6,319		)	(17		)
Forwards-long (Slurry)	24,837		87.65		—		2,177			2,210			33
Forwards-short (Catfeed)	(10,414	)	—		111.57		(1,162		)	(1,202		)	(40		)
Forwards-short (Slop)	(12,428	)	—		78.25		(972		)	(1,017		)	(44		)
Futures-short (Crude)	(362,000	)	—		87.74		(31,763		)	(33,239		)	(1,476		)
Futures-short (Gasoline)	(18,000	)	—		95.48		(1,719		)	(2,088		)	(369		)
Futures-long (Diesel)	18,000		120.42		—		2,168			2,292			125
Description of Activity	Contract Volume (in barrels)		Wtd Avg Contract Spread		Wtd Avg Market Spread		Contract Value			Fair Value			Gain (Loss)
							(in thousands)
Futures-swaps	(5,760,000	)	$	25.30	$	25.03	$	(145,710	)	$	(144,196	)	$	1,514

Interest Rate Risk

As of December 31, 2012, all of our outstanding debt was at fixed rates.

ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA.

The Financial Statements and Schedule are included as an annex of this Annual Report on Form 10-K. See the Index to Financial Statements and Schedule on page F-1.

ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING ANDFINANCIAL DISCLOSURE.

None.

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ITEM 9A. CONTROLS AND PROCEDURES.

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 amended (the “Exchange Act”)) 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 furnish under the Exchange Act is recorded, processed, summarized and reported, within the time periods specified in the SEC's rules and forms including, without limitation, controls and procedures designed to ensure that information required to be disclosed by us in the reports that we file or furnish under the Exchange Act is accumulated and communicated to our management, including our principal executive and principal financial officers, as appropriate to allow timely decisions regarding required disclosures.

Management's Report on Internal Control over Financial Reporting

Our management is responsible for establishing and maintaining adequate “internal control over financial reporting” (as defined in Rule 13a-15(f) under the Exchange Act) for Alon Refining Krotz Springs, Inc. Our management evaluated the effectiveness of our internal control over financial reporting as of December 31, 2012. In management's evaluation, it used the criteria set forth by the Committee of Sponsoring Organizations of the Treadway Commission (COSO) in Internal Control-Integrated Framework. Management believes that as of December 31, 2012, our internal control over financial reporting was effective based on those criteria.

Changes in Internal Control Over Financial Reporting

There has been no change in our internal control over financial reporting during the year ended December 31, 2012 that has materially affected, or is reasonably likely to materially affect, our internal control over financial reporting.

Certifications

Included in this Annual Report on Form 10-K are certifications of our Chief Executive Officer and Chief Financial Officer which are required in accordance with Rule 13a-14 of the Exchange Act. This section includes the information concerning the controls and controls evaluation referred to in the certifications.

ITEM 9B. OTHER INFORMATION.

None.

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PART III

Certain portions of Items 10, 11 and 12 of this Part III of Form 10-K have been omitted under the reduced disclosure format permitted by General Instruction I(2)(c) of Form 10-K.

ITEM 10. DIRECTORS, EXECUTIVE OFFICERS AND CORPORATE GOVERNANCE.

Management

Our current directors and executive officers, their ages as of January 31, 2013, and their business experience during the past five years are set forth below:

Name	Age	Position
David Wiessman	58	Executive Chairman of the Board of Directors
Jeff D. Morris	61	Vice Chairman of the Board of Directors
Paul Eisman	57	Director, Chief Executive Officer and President
Shai Even	44	Director, Senior Vice President and Chief Financial Officer
Joseph A. Concienne, III	62	Director
Claire A. Hart	57	Senior Vice President
Alan Moret	58	Vice President of Supply
Michael Oster	41	Vice President of Mergers and Acquisitions
Gregg Byers	58	Vice President of Refining
Kyle McKeen	49	Vice President of Wholesale Marketing (Alon USA Partners, LP)

David Wiessman has served as Executive Chairman of our Board of Directors since July 2008. Mr. Wiessman has also served as Executive Chairman of the Board of Directors of Alon USA since July 2000 and served as President and Chief Executive Officer of Alon USA from its formation in 2000 until May 2005. Mr. Wiessman has over 35 years of oil industry and marketing experience. Since 1994, Mr. Wiessman has been Chief Executive Officer, President and a director of Alon Israel Oil Company, Ltd., or Alon Israel, Alon USA's parent company. In 1992, Bielsol Investments (1987) Ltd. acquired a 50% interest in Alon Israel. In 1987, Mr. Wiessman became Chief Executive Officer of, and a stockholder in, Bielsol Investments (1987) Ltd. In 1976, after serving in the Israeli Air Force, he became Chief Executive Officer of Bielsol Ltd., a privately-owned Israeli company that owns and operates gasoline stations and owns real estate in Israel. Mr. Wiessman is also Executive Chairman of the Board of Directors of Blue Square-Israel, Ltd., which is listed on the New York Stock Exchange, or NYSE, and the Tel Aviv Stock Exchange, or TASE; Executive Chairman of Blue Square Real Estate Ltd., which is listed on the TASE, and Executive Chairman of the Board and President of Dor-Alon Energy in Israel (1988) Ltd., which is listed on the TASE, and all of which are subsidiaries of Alon Israel.

Jeff D. Morris has served as our Vice Chairman of the Board of Directors since May 2011 and a director since July 2008. Mr. Morris also served as our Chief Executive Officer from July 2008 to May 2011 and as President from July 2008 until March 2010.  Mr. Morris has served as the Vice Chairman of the Board of Directors of Alon USA since May 2011 and director since May 2005.  He also served as Alon USA's Chief Executive Officer from May 2005 to May 2011, Alon USA's Chief Executive Officer of its operating subsidiaries from July 2000 to May 2011, Alon USA's President from May 2005 until March 2010 and President of its operating subsidiaries from July 2000 until March 2010. Prior to joining Alon USA, he held various positions at FINA, Inc., where he began his career in 1974. Mr. Morris served as Vice President of FINA's South Eastern Business Unit from 1998 to 2000 and as Vice President of its South Western Business Unit from 1995 to 1998. In these capacities, he was responsible for both the Big Spring refinery and FINA's Port Arthur refinery and the crude oil gathering assets and marketing activities for both business units.

Paul Eisman was appointed to serve as our Chief Executive Officer in May 2011 and our President in March 2010 in connection with his appointments as Chief Executive Officer and President of Alon USA. Prior to joining Alon USA, Mr. Eisman was Executive Vice President, Refining & Marketing Operations at Frontier Oil Corporation from 2006 to 2009 and held various positions at KBC Advanced Technologies from 2003 to 2006, including Vice President of North American Operations. During 2002, Mr. Eisman was Senior Vice President of Planning for Valero Energy Corporation following Valero's acquisition of Ultramar Diamond Shamrock. Prior to the acquisition, Mr. Eisman had a 24-year career with Ultramar Diamond Shamrock, serving in many technical and operational roles including Executive Vice President of Corporate Development and Refinery Manager at the McKee refinery.

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Shai Even is our Senior Vice President and Chief Financial Officer and has served as an officer since July 2008 and a director since May 2008. Mr. Even has also served as a Senior Vice President of Alon USA since August 2008 and as Alon USA's Chief Financial Officer since December 2004. Mr. Even served as a Vice President of Alon USA from May 2005 to August 2008 and Treasurer from August 2003 until March 2007.

Joseph A. Concienne, III has served as a director since July 2008 and served as our Vice President from July 2008 until his retirement in February 2011. Mr. Concienne also served as Senior Vice President of Refining of Alon USA from August 2008 to February 2011and served as Senior Vice President of Refining and Transportation of Alon USA from May 2007 to August 2008 and Vice President of Refining and Transportation of Alon USA from March 2001 to May 2007. Prior to joining Alon USA, Mr. Concienne served as Director of Operations/General Manager for PolyOne Corporation in Seabrook, Texas from 1998 to 2001. He served as Vice President/General Manager for Valero Refining and Marketing, Inc. in 1998, and as Manager of Refinery Operations and Refinery Manager for Phibro Energy Refining (now known as Valero Refining and Marketing, Inc.) from 1985 to 1998.

Claire A. Hart is our Senior Vice President and has served as an officer since July 2008. Mr. Hart has also served as Senior Vice President of Alon USA since January 2004 and served as Alon USA's Chief Financial Officer and Vice President from August 2000 to January 2004. Prior to joining Alon USA, he held various positions in the Finance, Accounting and Operations departments of FINA for 13 years, serving as Treasurer from 1998 to August 2000 and as General Manager of Credit Operations from 1997 to 1998.

Alan Moret is our Vice President of Supply and has served as an officer since July 2008. Mr. Moret has also served as Senior Vice President of Supply of Alon USA since August 2008. Mr. Moret served as Alon USA's Senior Vice President of Asphalt Operations from August 2006 to August 2008, with responsibility for asphalt operations and marketing at Alon USA's refineries and asphalt terminals. Prior to joining Alon USA, Mr. Moret was President of Paramount Petroleum Corporation from November 2001 to August 2006. Prior to joining Paramount Petroleum Corporation, Mr. Moret held various positions with Atlantic Richfield Company, most recently as President of ARCO Crude Trading, Inc. from 1998 to 2000 and as President of ARCO Seaway Pipeline Company from 1997 to 1998.

Michael Oster is our Vice President of Mergers and Acquisitions and has served as an officer since August 2009. Mr. Oster has also served as Senior Vice President of Mergers and Acquisitions of Alon USA since August 2008 and General Manager of Commercial Transactions of Alon USA from January 2003 to August 2008. Prior to joining Alon USA, Mr. Oster was a partner in the Israeli law firm, Yehuda Raveh and Co.

Gregg Byers has served as our Vice President of Refining since February 2012, with responsibility for operations at our refinery. Mr. Byers rejoined Alon USA in September 2011 as Senior Director of Engineering Services.  Mr. Byers has been employed in the refining industry for over 35 years, most recently with Sinclair Oil Corporation as Operations Manager of Sinclair's Wyoming refinery from 2008 to 2011. Prior to this, Mr. Byers served as Engineering & Project Development Director at our refinery under Alon USA's ownership in 2008 and Valero Energy Corporation's ownership from 2001 to 2008.

Kyle McKeen is the Vice President of Wholesale Marketing of Alon USA Partners GP, LLC, the general partner of Alon USA Partners, LP, in August 2012 and has served as President and Chief Executive Officer of Alon Brands, Inc., our parent company's subsidiary that manages retail operations, since May 2008. From 2005 to 2008, Mr. McKeen served as President and Chief Operating Officer of Carter Energy, an independent energy marketer supporting over 600 retailers by providing fuel supply, merchandising and marketing support, and consulting services. Prior to joining Carter Energy in 2005, Mr. McKeen was a member of the Board of Managers of Alon USA Interests, LLC from September 2002 to 2005 and held numerous positions of increasing responsibilities with Alon Energy, including Vice President of Marketing.

Corporate Governance

We do not have an audit committee or a compensation committee. The executive officers of our parent company serve as members of our board of directors. Our executive officers are subject to the Corporate Governance Guidelines and Code of Business Conduct and Code of Ethics of our parent company. Copies of such documents are available free of charge through our parent's internet website at www.alonusa.com. We do not have an internet website.

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ITEM 11. EXECUTIVE COMPENSATION.

The following table sets forth the name and title of our principal executive officer and principal financial officer and our three other most highly compensated executive officers, which we refer to as the named executive officers:

Name	Title
Paul Eisman	Chief Executive Officer and President
Shai Even	Senior Vice President and Chief Financial Officer
Michael Oster	Vice President of Mergers and Acquisitions
Alan Moret	Vice President of Supply
Kyle McKeen	Vice President of Marketing (Alon USA Partners, LP)

Our named executive officers are also executive officers and employees of our parent company and are compensated by our parent company in their capacities as such. See “Certain Relationships and Related Party Transactions.” We do not directly employ our named executive officers. Our parent company's compensation committee establishes the base salary, bonus and other elements of compensation for its executive officers, and such determinations are not subject to approvals by our board of directors.

The objectives of our parent company's compensation policies are to attract, motivate and retain qualified management and personnel who are highly talented while ensuring that executive officers and other employees are compensated in a manner that advances both the short and long-term interests of stockholders. In pursuing these objectives, our parent company's compensation committee believes that compensation should reward executive officers and other employees for both their personal performance and the performance of our parent company and its subsidiaries.

Our parent company's management provides compensation recommendations to its compensation committee. However, the final determination of a compensation package for the named executive officers is made solely by the compensation committee, except with respect to the compensation packages of Messrs. Wiessman and Eisman. The compensation package for Mr. Eisman is determined by Mr. Wiessman in consultation with our parent company's board of directors. The compensation package for Mr. Wiessman is determined by our parent company's board of directors, excluding Mr. Wiessman. Our parent company does not currently engage any consultants relating to executive and/or director compensation practices.

Employment Agreements and Change of Control Arrangements

Paul Eisman. Our parent company is party to a Management Employment Agreement with Paul Eisman, the initial term of which is through March 1, 2015, and the term of which automatically renews for one-year terms unless terminated by either party. Mr. Eisman currently receives a base salary of $408,000 per year and is eligible for annual merit increases. Under his employment agreement, Mr. Eisman is entitled to participate in our parent company's annual cash bonus plans, pension plan and benefits restoration plan. Additionally, our parent company is required to provide Mr. Eisman with additional benefits to the extent such benefits are made available to other employees, including disability, hospitalization, medical and retiree health benefits and life insurance. Mr. Eisman is subject to a covenant not to compete during the term of his employment. In the event that Mr. Eisman is terminated without cause (as defined in the agreement) or resigns upon at least 30 days' prior written notice for good reason (as defined in the agreement), he will be entitled to receive his base salary through the termination date, the prorated share of his annual bonus and a severance payment equal to nine months' base salary. This agreement also prohibits Mr. Eisman from disclosing our parent company's proprietary information received through his employment.

Shai Even. Our parent company is party to an Executive Employment Agreement with Shai Even to serve for one-year terms upon automatic renewal each August 1st unless terminated by either party. Mr. Even currently receives a base salary of $306,000 per year and is eligible for annual merit increases. Under his employment agreement, Mr. Even is entitled to participate in our parent company's annual cash bonus plans, pension plan and benefits restoration plan. Additionally, our parent company is required to provide Mr. Even with additional benefits to the extent such benefits are made available to other employees, including disability, hospitalization, medical and retiree health benefits and life insurance. Mr. Even is subject to a covenant not to compete during the term of his employment. In the event that Mr. Even is terminated without cause (as defined in the agreement) or resigns upon at least 30 days' prior written notice for good reason (as defined in the agreement), he will be entitled to receive his base salary through the termination date, the prorated share of his annual bonus and a severance payment equal to nine months' base salary. This agreement also prohibits Mr. Even from disclosing our parent company's proprietary information received through his employment.

Michael Oster. Our parent company is party to a Management Employment Agreement with Michael Oster to serve for one-year terms upon automatic renewal each January 1st unless terminated by either party. Mr. Oster currently receives a base salary of $260,100 per year and is eligible for annual merit increases. Under his employment agreement, Mr. Oster is entitled to

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participate in our parent company's annual cash bonus plans, pension plan and benefits restoration plan. Additionally, our parent company is required to provide Mr. Oster with additional benefits to the extent such benefits are made available to other employees, including disability, hospitalization, medical and retiree health benefits and life insurance. Mr. Oster is subject to a covenant not to compete during the term of his employment. In the event that Mr. Oster is terminated without cause (as defined in the agreement) or resigns upon at least 30 days' prior written notice for good reason (as defined in the agreement), he will be entitled to receive his base salary through the termination date, the prorated share of his annual bonus and a severance payment equal to nine months' base salary. This agreement also prohibits Mr. Oster from disclosing our parent company's proprietary information received through his employment.

Alan Moret. Our parent company is party to an Employment Agreement with Alan Moret, the term of which automatically renews each November for one-year terms unless terminated by either party. Mr. Moret currently receives a base salary of $318,101 per year and is eligible for annual merit increases. Under his employment agreement, Mr. Moret is entitled to participate in our parent company's annual cash bonus plans and a 401(k) plan with matching contribution from Alon of up to 6% of Mr. Moret's base salary. Additionally, our parent company is required to provide Mr. Moret with additional benefits to the extent such benefits are made available to other employees, including disability, hospitalization, medical and retiree health benefits and life insurance. In the event that (i) Mr. Moret is terminated without cause (as defined in the agreement), (ii) our parent company does not elect to extend the employment term (as defined in the agreement) or (iii) Mr. Moret resigns upon at least 90 days' prior written notice for good reason (as defined in the agreement), he will be entitled to receive any earned but unpaid annual bonus as of the date of termination for the previous year and a severance payment equal to four years' base salary, provide that, he will receive an additional years' base salary if our parent company terminates his employment prior to the then effective employment term. In the event that Mr. Moret's employment is terminated due to death or disability (as defined in the agreement), he will be entitled to receive any earned but unpaid annual bonus as of the date of termination for the previous year, the prorated share of his annual bonus for the current year and a severance payment equal to four years' base salary. This agreement also prohibits Mr. Moret from disclosing our parent company's proprietary information received through his employment.

Kyle McKeen. Our parent company is a party to an Executive Employment Agreement with Kyle McKeen, the initial term of which is through May 1, 2013, and the term of which automatically renews for one-year terms unless terminated by either party. Mr. McKeen currently receives a base salary of $315,200 per year and is eligible for annual merit increases. Under his employment agreement, Mr. McKeen is entitled to participate in our parent company's annual cash bonus plans, pension plan and benefits restoration plan. Additionally, our parent company is required to provide Mr. McKeen with additional benefits to the extent such benefits are made available to other employees, including disability, hospitalization, medical and retiree health benefits and life insurance. Mr. McKeen is subject to a covenant not to compete during the term of his employment. In the event that Mr. McKeen is terminated without Cause (as defined in the agreement) or resigns upon at least 30 days' prior written notice for Good Reason (as defined in the agreement), he will be entitled to receive his base salary through the termination date, the prorated share of his annual bonus and a severance payment equal to twelve months' base salary. This agreement also prohibits Mr. McKeen from disclosing our parent company's proprietary information received through his employment.

Compensation of Directors

Our directors do not receive any compensation in respect of their services as directors of our company.

Compensation Committee Interlocks and Insider Participation

We do not have a compensation committee. Our parent company has a compensation committee consisting of Itzhak Bader, a director, and David Wiessman, its and our Executive Chairman of the Board. Our parent company's compensation committee determines the compensation of the executive officers other than for Mr. Wiessman.  Mr. Wiessman's compensation is determined by our parent company's board of directors, excluding Mr. Wiessman.

None of our executive officers, other than Messrs. Wiessman, serves as a member of the board of directors or compensation committee of any entity that has one or more of its executive officers serving as a member of the board of directors. As described above, Messrs. Wiessman serves as a member  of the board of directors and compensation committee of our parent company, whose executive officers serve as members of our board of directors.

ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT ANDRELATED STOCKHOLDER MATTERS.

Omitted under the reduced disclosure format permitted by General Instruction I(2)(a) of Form 10-K.

ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS, AND DIRECTOR INDEPENDENCE.

Omitted under the reduced disclosure format permitted by General Instruction I(2)(a) of Form 10-K.

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ITEM 14. PRINCIPAL ACCOUNTANT FEES AND SERVICES.

Audit Fees. The aggregate fees billed by KPMG LLP (“KPMG”) for professional services rendered for the audit of our annual financial statements, the review of the financial statements included in our annual report on Form 10-K and quarterly reports on Form 10-Q were $0.2 million for the year ended December 31, 2012.

Audit-Related Fees. There were no fees billed by KPMG for assurance and related services related to the performance of audits or review of our financial statements and not described above under “Audit Fees” in 2012.

Tax Fees. No fees were billed by KPMG for professional services rendered for tax compliance, tax advice and tax planning in 2012.

All Other Fees. No fees were billed by KPMG for products and services not described above in 2012.

Pre-Approval Policies and Procedures. In general, all engagements of our outside auditors, whether for auditing or non-auditing services, must be pre-approved by the Board of Directors. During 2012, all of the services performed for us by KPMG were pre-approved by the Board of Directors. The Board of Directors has considered the compatibility of non-audit services with KPMG's independence.

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PART IV

ITEM 15. EXHIBITS AND FINANCIAL STATEMENT SCHEDULES.

The following documents are filed as part of this report:

1. Financial Statements. See “Index to Financial Statements” on page F-1.

2. Financial Statement Schedules and Other Financial Information. All financial statement schedules are omitted because either they are not applicable or the required information is included in the financial statements or notes included herein.

3. Exhibits. Exhibits filed as part of this Form 10-K are as follows:

Exhibit No.	Description
3.1	Certificate of Incorporation of Alon Refining Krotz Springs, Inc., as amended by the Certificate of Amendment to Certificate of Incorporation of Alon Refining Krotz Springs, Inc. (incorporated by reference to Exhibit 3.1 to Form S-4, filed by Alon Refining Krotz Springs, Inc. on December 22, 2009, SEC File No. 333-163942).
3.2	Amended and Restated Bylaws of Alon Refining Krotz Springs, Inc. (incorporated by reference to Exhibit 3.2 to Form S-4, filed by Alon Refining Krotz Springs, Inc. on December 22, 2009, SEC File No. 333-163942).
4.1	Indenture, dated as of October 22, 2009, by and among Alon Refining Krotz Springs, Inc. and Wilmington Trust FSB, as Trustee (incorporated by reference to Exhibit 4.1 to Form 8-K, filed by Alon USA Energy, Inc. on October 23, 2009, SEC File No. 001-32567).
10.1	Stock Purchase Agreement, dated May 7, 2008, between Valero Refining and Marketing Company and Alon Refining Krotz Springs, Inc. (incorporated by reference to Exhibit 10.1 to Form 8-K, filed by Alon USA Energy, Inc. on May 13, 2008, SEC File No. 001-32567).
10.2	First Amendment to Stock Purchase Agreement, dated as of July 3, 2008, by and among Valero Refining and Marketing Company, Alon Refining Krotz Springs, Inc. and Valero Refining Company-Louisiana (incorporated by reference to Exhibit 10.1 to Form 8-K, filed by Alon USA Energy, Inc. on July 10, 2008, SEC File No. 001-32567).
10.3	Registration Rights Agreement, dated October 22, 2009, between Alon Refining Krotz Springs, Inc. and Jefferies & Company, Inc. (incorporated by reference to Exhibit 10.2 to Form 8-K, filed by Alon USA Energy, Inc. on October 23, 2009, SEC File No. 001-32567).
10.4	Purchase Agreement, dated October 13, 2009, between Alon Refining Krotz Springs, Inc. and Jefferies & Co. (incorporated by reference to Exhibit 10.1 to Form 8-K, filed by Alon USA Energy, Inc. on October 19, 2009, SEC File No. 001-32567).
10.5†	Offtake Agreement, dated as of July 3, 2008, by and between Valero Marketing and Supply Company and Alon Refining Krotz Springs, Inc. (incorporated by reference to Exhibit 10.5 to Form S-4/A, filed by Alon Refining Krotz Springs, Inc. on January 12, 2010, SEC File No. 333-163942).
10.6†	Earnout Agreement, dated as of July 3, 2008, by and between Valero Refining and Marketing Company and Alon Refining Krotz Springs, Inc. (incorporated by reference to Exhibit 10.6 to Form S-4/A, filed by Alon Refining Krotz Springs, Inc. on January 12, 2010, SEC File No. 333-163942).
10.7†	First Amendment to Earnout Agreement, dated as of August 27, 2009, by and between Valero Refining and Marketing Company and Alon Refining Krotz Springs, Inc. (incorporated by reference to Exhibit 10.7 to Form S-4/A, filed by Alon Refining Krotz Springs, Inc. on January 12, 2010, SEC File No. 333-163942).
10.8*	Executive Employment Agreement, dated as of July 31, 2000, between Jeff D. Morris and Alon USA GP, Inc., as amended by the Amendment to Executive/Management Employment Agreement, dated May 1, 2005 (incorporated by reference to Exhibit 10.23 to Form S-1, filed by Alon USA Energy, Inc. on May 11, 2005, SEC File No. 333-124797).
10.9*	Second Amendment to Executive Employment Agreement, dated as of November 4, 2008, between Jeff D. Morris and Alon USA GP, LLC (incorporated by reference to Exhibit 10.9 to Form 10-Q, filed by Alon USA Energy, Inc. on November 7, 2008, SEC File No. 001-32567).
10.10*	Executive Employment Agreement between Jeff D. Morris and Alon USA Energy, Inc., dated May 3, 2011, (incorporated by reference to Exhibit 10.1 to Form 8-K, filed by Alon USA Energy, Inc. on May 6, 2011, SEC File No. 001-32567).
10.11*	Management Employment Agreement, dated as of March 1, 2010, between Paul Eisman and Alon USA GP, LLC. (incorporated by reference to Exhibit 10.22 to Form 10-K, filed by Alon USA Energy, Inc. on March 15, 2011 SEC File No. 001-32567).
10.12*	Agreement of Principles of Employment, dated as of December 22, 2009, between David Wiessman and Alon USA Energy, Inc. (incorporated by reference to Exhibit 10.44 to Form 10-K, filed by Alon USA Energy, Inc. on March 13, 2012, SEC File No. 001-32567).

26

Exhibit No.	Description
10.13*	Amended and Restated Employment Agreement by and between Paramount Petroleum Corporation and Alan P. Moret, dated July 8, 2011 (incorporated by reference to Exhibit 10.1 to Form 8-K, filed by Alon USA Energy, Inc. on July 13, 2011, SEC File No. 001-32567).
10.14*	Executive Employment Agreement, dated as of August 1, 2003, between Shai Even and Alon USA GP, LLC (incorporated by reference to Exhibit 10.49 to Form 10-K, filed by Alon USA Energy, Inc. on March 15, 2007, SEC File No. 001-32567).
10.15*	Amendment to Executive Employment Agreement, dated as of November 4, 2008, between Shai Even and Alon USA GP, LLC. (incorporated by reference to Exhibit 10.14 to Form 10-Q, filed by Alon USA Energy, Inc. on November 7, 2008, SEC File No. 001-32567).
10.16*	Management Employment Agreement, dated as of October 30, 2008, between Michael Oster and Alon USA GP, LLC (incorporated by reference to Exhibit 10.71 to Form 10-K, filed by Alon USA Energy, Inc. on April 10, 2009, SEC File No. 001-32567).
10.17*	Description of Annual Bonus Plans (incorporated by reference to Exhibit 10.2 to Form 10-Q, filed by Alon USA Energy, Inc. on May 6, 2008, SEC File No. 001-32567).
10.18*	Change of Control Incentive Bonus Program (incorporated by reference to Exhibit 10.29 to Form S-1, filed by Alon USA Energy, Inc. on May 11, 2005, SEC File No. 333-124797).
10.19*	Form of Officer Indemnification Agreement (incorporated by reference to Exhibit 10.32 to Form S-1, filed by Alon USA Energy, Inc. on May 11, 2005, SEC File No. 333-124797).
10.20*	Form of Director and Officer Indemnification Agreement (incorporated by reference to Exhibit 10.33 to Form S-1, filed by Alon USA Energy, Inc. on May 11, 2005, SEC File No. 333-124797).
10.21*	Alon USA Energy, Inc. Amended and Restated 2005 Incentive Compensation Plan (incorporated by reference to Exhibit 10.1 to Form 8-K, filed by Alon USA Energy, Inc.  on May 7, 2010, SEC File No. 001-32567).
10.22*	Form of Restricted Stock Award Agreement relating to Director Grants pursuant to Section 12 of the Alon USA Energy, Inc. 2005 Incentive Compensation Plan (incorporated by reference to Exhibit 10.1 to Form 8-K, filed by Alon USA Energy, Inc. on August 5, 2005, SEC File No. 001-32567).
10.23*	Form of Restricted Stock Award Agreement relating to Participant Grants pursuant to Section 8 of the Alon USA Energy, Inc. 2005 Incentive Compensation Plan (incorporated by reference to Exhibit 10.1 to Form 8-K, filed by Alon USA Energy, Inc. on August 23, 2005, SEC File No. 001-32567).
10.24*	Form II of Restricted Stock Award Agreement relating to Participant Grants pursuant to Section 8 of the Alon USA Energy, Inc. 2005 Incentive Compensation Plan (incorporated by reference to Exhibit 10.3 to Form 8-K, filed by Alon USA Energy, Inc. on November 8, 2005, SEC File No. 001-32567).
10.25*	Form of Appreciation Rights Award Agreement relating to Participant Grants pursuant to Section 7 of the Alon USA Energy, Inc. 2005 Incentive Compensation Plan (incorporated by reference to Exhibit 10.1 to Form 8-K, filed by Alon USA Energy, Inc. on March 12, 2007, SEC File No. 001-32567).
10.26*	Form of Amendment to Appreciation Rights Award Agreement relating to Participant Grants pursuant to Section 7 of the Alon USA Energy, Inc. 2005 Incentive Compensation Plan (incorporated by reference to Exhibit 10.2 to Form 8-K, filed by Alon USA Energy, Inc. on January 27, 2010, SEC File No. 001-32567).
10.27*	Form II of Appreciation Rights Award Agreement relating to Participant Grants pursuant to Section 7 of the Alon USA Energy, Inc. 2005 Incentive Compensation Plan (incorporated by reference to Exhibit 10.1 to Form 8-K, filed by Alon USA Energy, Inc. on January 27, 2010, SEC File No. 001-32567.
10.28*	Award Agreement between Alon USA Energy, Inc. and Paul Eisman, dated May 5, 2011, (incorporated by reference to Exhibit 10.1 to Form 8-K, filed by Alon USA Energy, Inc. on May 9, 2011, SEC File No. 001-32567).
10.29*	Form of Award Agreement relating to Executive Officer Restricted Stock Grants pursuant to the Alon USA Energy, Inc. 2005 Amended and Restated Incentive Compensation Plan (incorporated by reference to Exhibit 10.2 to Form 8-K, filed by Alon USA Energy, Inc. on May 9, 2011, SEC File No. 001-32567).
10.30	Credit Agreement, dated May 28, 2010, by and between Alon Refining Krotz Springs, Inc. and Goldman Sachs Bank USA, as Issuing Bank (incorporated by reference to Exhibit 10.5 to Form 10-Q, filed by Alon USA Energy, Inc. on August 9, 2010, SEC File No. 333-124797).
10.31	First Amendment, dated as of July 31, 2012, to the Credit Agreement, dated May 28, 2010, by and between Alon Refining Krotz Springs, Inc. and Goldman Sachs Bank USA, as Issuing Bank (incorporated by reference to Exhibit 10.7 to Form 10-Q, filed by Alon USA Energy, Inc., on August 9, 2012, SEC File No. 001-32567).
10.32	Amended and Restated Supply and Offtake Agreement, dated May 26, 2010 by and between Alon Refining Krotz Springs, Inc. and J. Aron & Company (incorporated by reference to Exhibit 10.6 to Form 10-Q, filed by Alon USA Energy, Inc. on August 9, 2010, SEC File No. 333-124797).
10.33	First Amendment to the Supply and Offtake Agreement, dated January 20, 2011, by and between Alon Refining Krotz Springs, Inc. and J. Aron & Company (incorporated by reference to Exhibit 10.2 to Form 10-Q, filed by the Company on May 10, 2011, SEC File No. 001-32567).

27

Exhibit No.	Description
10.34	Amended and Restated Second Amendment to the Supply and Offtake Agreement, dated March 1, 2011, by and between Alon Refining Krotz Springs, Inc. and J. Aron & Company (incorporated by reference to Exhibit 10.3 to Form 10-Q, filed by the Company on May 10, 2011, SEC File No. 001-32567).
10.35	Supplemental Agreement to Supply and Offtake Agreement, dated October 31, 2011, between Alon Refining Krotz Springs, Inc. and J. Aron & Company (incorporated by reference to Exhibit 10.1 to Form 10-Q, filed by the Company on November 7, 2011, SEC File No. 001-32567).
10.36	Amendment, dated as of July 20, 2012, to the Amended and Restated Supply and Offtake Agreement, dated May 28, 2010, by and between Alon Refining Krotz Springs, Inc. and J. Aron & Company (incorporated by reference to Exhibit 10.5 to Form 10-Q, filed by Alon USA Energy, Inc., on August 9, 2012, SEC File No. 001-32567).
23.1	Consent of KPMG LLP
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	Certification 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.
101	The following financial information from Alon Refining Krotz Springs, Inc.'s Annual Report on Form 10-K for the year ended December 31, 2012, formatted in XBRL (Extensible Business Reporting Language): (i) Balance Sheets, (ii) Statements of Operations, (iii) Statements of Comprehensive Loss, (iv) Statement of Stockholders' Equity, (v) Statements of Cash Flows and (vi) Notes to Financial Statements.

____________

*	Identifies management contracts and compensatory plans or arrangements.
†	Portions of the exhibit have been omitted pursuant to a request for confidential treatment. The confidential portions have been furnished to the SEC.

28

ALON REFINING KROTZ SPRINGS, INC.

INDEX TO FINANCIAL STATEMENTS

	Page
Audited Financial Statements:
Report of Independent Registered Public Accounting Firm	F-2
Balance Sheets as of December 31, 2012 and 2011	F-3
Statements of Operations for the Years Ended December 31, 2012, 2011 and 2010	F-4
Statements of Comprehensive Loss for the Years Ended December 31, 2012, 2011 and 2010	F-5
Statement of Stockholders' Equity for the Years Ended December 31, 2012, 2011 and 2010	F-6
Statements of Cash Flows for the Years Ended December 31, 2012, 2011 and 2010	F-7
Notes to Financial Statements	F-8

Report of Independent Registered Public Accounting Firm

The Board of Directors and Stockholders

Alon Refining Krotz Springs, Inc.:

We have audited the accompanying balance sheets of Alon Refining Krotz Springs, Inc. as of December 31, 2012 and 2011, and the related statements of operations, comprehensive loss, stockholders' equity and cash flows for each of the years in the three‑year period ended December 31, 2012. These financial statements are the responsibility of the Company's management. Our responsibility is to express an opinion on these financial statements based on our audits.

We conducted our audits in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. An audit includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements. An audit also includes assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audits provide a reasonable basis for our opinion.

In our opinion, the financial statements referred to above present fairly, in all material respects, the financial position of Alon Refining Krotz Springs, Inc. as of December 31, 2012 and 2011, and the results of their operations and their cash flows for each of the years in the three‑year period ended December 31, 2012, in conformity with U.S. generally accepted accounting principles.

/s/ KPMG LLP

Dallas, Texas

March 22, 2013

F-2

ALON REFINING KROTZ SPRINGS, INC.

BALANCE SHEETS

(dollars in thousands, except per share data)

	As of December 31,
	2012			2011
ASSETS
Current assets:
Cash and cash equivalents	$	1,107		$	386
Accounts and other receivables, net	38,412			38,497
Inventories	44,796			38,357
Prepaid expenses and other current assets	2,354			498
Total current assets	86,669			77,738
Property, plant and equipment, net	343,321			349,083
Other assets, net	22,368			27,072
Total assets	$	452,358		$	453,893
LIABILITIES AND STOCKHOLDERS’ EQUITY
Current liabilities:
Accounts payable	$	380,329		$	280,811
Accrued liabilities	12,499			21,199
Total current liabilities	392,828			302,010
Other non-current liabilities	29,436			34,163
Long-term debt	211,573			209,324
Total liabilities	633,837			545,497
Commitments and contingencies (Note 15)
Stockholders’ equity:
Class A Common stock, par value $0.01, 75,000 shares authorized: 50,111 shares issued and outstanding at December 31, 2012 and 2011	—			—
Class B Common stock, par value $0.01, 1,000 shares authorized; 90 and 315 shares issued and outstanding at December 31, 2012 and 2011, respectively	—			—
Accumulated other comprehensive income, net of income tax	1,514			—
Additional paid-in capital	167,656			167,656
Retained deficit	(350,649		)	(259,260		)
Total stockholders' equity	(181,479		)	(91,604		)
Total liabilities and stockholders' equity	$	452,358		$	453,893

The accompanying notes are an integral part of these financial statements.

F-3

ALON REFINING KROTZ SPRINGS, INC.

STATEMENTS OF OPERATIONS

(dollars in thousands)

	Year Ended December 31,
	2012			2011			2010
Net sales	$	2,881,242		$	2,533,092		$	1,254,663
Operating costs and expenses:
Cost of sales	2,674,978			2,463,950			1,218,347
(Gains) losses on commodity swaps	116,020			(30,040		)	7,837
Direct operating expenses	95,713			79,972			62,321
Selling, general and administrative expenses	7,828			6,827			6,890
Depreciation and amortization	23,882			22,645			21,844
Total operating costs and expenses	2,918,421			2,543,354			1,317,239
Loss on disposition of assets	(2,504		)	—			—
Operating loss	(39,683		)	(10,262		)	(62,576		)
Interest expense	(44,417		)	(40,977		)	(47,695		)
Other loss, net	(7,289		)	(36,232		)	(4,105		)
Loss before income tax benefit	(91,389		)	(87,471		)	(114,376		)
Income tax benefit	—			—			—
Net loss	$	(91,389	)	$	(87,471	)	$	(114,376	)

The accompanying notes are an integral part of these financial statements.

F-4

ALON REFINING KROTZ SPRINGS, INC.

STATEMENTS OF COMPREHENSIVE LOSS

(dollars in thousands)

	Year Ended December 31,
	2012			2011			2010
Net loss	$	(91,389	)	$	(87,471	)	$	(114,376	)
Other comprehensive income, net of tax:
Commodity contracts designated as cash flow hedges:
Unrealized holding gain (loss) arising during period, net of tax	(67,318		)	—			—
Less: reclassification adjustments for gain (loss) realized in net loss, net of tax	(68,832		)	—			(7,240		)
Net gain, net of tax	1,514			—			7,240
Total other comprehensive income, net of tax	1,514			—			7,240
Comprehensive loss	$	(89,875	)	$	(87,471	)	$	(107,136	)

The accompanying notes are an integral part of these financial statements.

F-5

ALON REFINING KROTZ SPRINGS, INC.

STATEMENT OF STOCKHOLDERS' EQUITY

(dollars in thousands)

	Common Stock		Additional Paid-In Capital		Accumulated Other Comprehensive Income (Loss)			Retained Deficit			Total
Balance at December 31, 2009	$	—	$	126,656	$	(7,240	)	$	(57,413	)	$	62,003
Capital contribution from parent	—		41,000		—			—			41,000
Net loss	—		—		—			(114,376		)	(114,376		)
Fair value of commodity derivative contracts, net of tax of $0	—		—		7,240			—			7,240
Balance at December 31, 2010	—		167,656		—			(171,789		)	(4,133		)
Net loss	—		—		—			(87,471		)	(87,471		)
Balance at December 31, 2011	—		167,656		—			(259,260		)	(91,604		)
Net loss	—		—		—			(91,389		)	(91,389		)
Fair value of commodity derivative contracts, net of tax of $0	—		—		1,514			—			1,514
Balance at December 31, 2012	$	—	$	167,656	$	1,514		$	(350,649	)	$	(181,479	)

The accompanying notes are an integral part of these financial statements.

F-6

ALON REFINING KROTZ SPRINGS, INC. STATEMENTS OF CASH FLOWS (dollars in thousands)
	Year Ended December 31,
	2012			2011			2010
Cash flows from operating activities:
Net loss	$	(91,389	)	$	(87,471	)	$	(114,376	)
Adjustments to reconcile net loss to cash provided by operating activities:
Depreciation and amortization	23,882			22,645			21,844
Amortization of debt issuance costs	2,246			2,044			2,512
Amortization of original issuance discount	2,249			1,946			1,685
Write-off of unamortized debt issuance costs	—			—			6,659
Loss on disposition of assets	2,504			—			—
Unrealized (gains) losses on commodity swaps	31,936			(31,936		)	—
Changes in operating assets and liabilities:
Accounts and other receivables, net	(32,593		)	(756		)	2,539
Inventories	(6,439		)	(19,796		)	23,924
Prepaid expenses and other current assets	(1,856		)	1,460			(1,343		)
Other assets, net	—			484			(885		)
Accounts payable	99,518			128,070			60,059
Accrued liabilities	(6,444		)	5,099			7,358
Other non-current liabilities	(4,727		)	6,566			19,724
Net cash provided by operating activities	18,887			28,355			29,700
Cash flows from investing activities:
Capital expenditures	(17,023		)	(18,909		)	(7,350		)
Capital expenditures for turnarounds and catalysts	(1,163		)	(2,649		)	(2,383		)
Earnout payments related to refinery acquisition	—			(6,562		)	(8,750		)
Proceeds from sale of assets	20			—			—
Net cash used in investing activities	(18,166		)	(28,120		)	(18,483		)
Cash flows from financing activities:
Deferred debt issuance costs	—			(126		)	(1,147		)
Cash received from inventory supply agreement	—			—			6,333
Revolving credit facilities, net	—			—			(83,287		)
Payments on long-term debt	—			—			—
Proceeds from parent equity investment	—			—			41,000
Net cash used in financing activities	—			(126		)	(37,101		)
Net increase (decrease) in cash and cash equivalents	721			109			(25,884		)
Cash and cash equivalents, beginning of period	386			277			26,161
Cash and cash equivalents, end of period	$	1,107		$	386		$	277
Supplemental cash flow information:
Cash paid for interest	$	40,896		$	37,542		$	43,165

The accompanying notes are an integral part of these financial statements.

F-7

ALON REFINING KROTZ SPRINGS, INC.

NOTES TO FINANCIAL STATEMENTS

(dollars in thousands, except as noted)

(1) Description and Nature of Business

Alon Refining Krotz Springs, Inc. (the “Company”), a subsidiary of Alon USA Energy, Inc. (“Alon USA”), owns and operates a high conversion crude oil refinery placed into service in 1980 with a crude oil throughput capacity of approximately 83,100 barrels per day (“bpd”). The refinery is strategically located on the Atchafalaya River in central Louisiana at the intersection of two crude oil pipeline systems and has direct access to the Colonial products pipeline system (“Colonial Pipeline”), providing the refinery with diversified access to both locally sourced and foreign crude oils, as well as distribution of the refinery's products to markets throughout the Southern and Eastern United States and along the Mississippi and Ohio Rivers. The refinery's residual fluid catalytic cracking unit allows it to produce a high percentage of light products with fewer processing units and lower maintenance costs compared to refineries utilizing conventional fluid catalytic cracking unit technologies. Sweet crude oil typically comprises 100% of the refinery's crude oil input and our refinery processing units are structured to yield approximately 101.5% of total feedstock input, meaning that for each 100 barrels of crude oil and feedstocks input into the refinery, it produces 101.5 barrels of refined products. Of the 101.5%, on average 99.0% is light finished products such as gasoline and distillates, including diesel and jet fuel, petrochemical feedstocks and liquefied petroleum gas, and the remaining 2.5% is primarily heavy oils.

(2) Basis of Presentation and Certain Significant Accounting Policies

(a) Basis of Presentation

These financial statements have been prepared in conformity with accounting principles generally accepted in the United States of America.

(b) Use of Estimates

The preparation of financial statements in conformity with accounting principles generally accepted in the United States of America requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates.

(c) Revenue Recognition

Revenues from sales of refined products are earned and realized upon transfer of title to the customer based on the contractual terms of delivery (including payment terms and prices). Title primarily transfers at the refinery or terminal when the refined product is loaded into the common carrier pipelines, trucks or railcars (free on board origin). In some situations, title transfers at the customer's destination (free on board destination).

The Company 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. These buy/sell transactions are included on a net basis in sales in the statements of operations and profits are recognized when the exchanged product is sold.

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 are recorded net, in cost of sales in the statements of operations.

(d) Cost Classifications

Cost of sales includes crude oil and other raw materials, inclusive of transportation costs. Cost of goods excludes depreciation and amortization, which is presented separately in the statements of operations.

Operating expenses include costs associated with the actual operations of the 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.

Selling, general and administrative expenses consist primarily of corporate overhead and marketing expenses.

Interest expense consists of interest expense, letters of credit, financing costs associated with crude oil purchases, fees, both the amortization and write-off of deferred debt issuance costs but excludes capitalized interest.

(e) Cash and Cash Equivalents

All highly-liquid instruments with a maturity of three months or less at the time of purchase are considered to be cash equivalents. Cash equivalents are stated at cost, which approximates market value.

F-8

ALON REFINING KROTZ SPRINGS, INC.

NOTES TO FINANCIAL STATEMENTS — (Continued)

(dollars in thousands, except as noted)

(f) Accounts Receivable

Credit is extended based on evaluation of the customer's financial condition and in certain circumstances, collateral, such as letters of credit or guarantees, are required. Credit losses are charged to reserve for bad debts when accounts are deemed uncollectible. Reserve for bad debts is based on a combination of current sales and specific identification methods.

(g) Inventories

Crude oil, refined products and blendstocks (including inventory consigned to others) are stated at the lower of cost or market. Cost is determined under the last-in, first-out (“LIFO”) valuation method. Cost of crude oil, refined products and blendstock inventories in excess of market value are charged to cost of sales. Such charges are subject to reversal in subsequent periods, not to exceed LIFO cost, if prices recover. Materials and supplies are stated at average cost.

Crude oil inventory consigned to others represents inventory that was sold to third parties with an obligation by the Company to repurchase the inventory at the end of the respective agreements. As a result of this requirement to repurchase inventory, no revenue was recorded on these transactions and the inventory volumes remain valued under the LIFO method.

(h) Hedging Activity

All derivative instruments are recorded in the balance sheet as either assets or liabilities measured at their fair value. The Company generally considers all commodity forwards, futures, swaps, and option contracts to be part of its risk management strategy. Accordingly, net unrealized gains and losses for changes in the fair value on open commodity derivative contracts are recognized in cost of sales or in other loss, net on the statement of operations.

The Company selectively designates certain commodity derivative contracts as cash flow hedges. The effective portion of the gains or losses associated with these derivative contracts designated and qualifying as cash flow hedges are initially recorded in accumulated other comprehensive income in the balance sheet and reclassified into the statement of operations in the period in which the underlying hedged forecasted transaction affects income. The amounts recorded into the statement of operations for commodity derivative contracts are recorded as a part of cost of sales. The ineffective portion of the gains or losses on the derivative contracts, if any, is recognized in the statement of operations as it is incurred.

The Company has designated the derivative transactions related to the inventory financing agreement as a fair value hedge of inventory. The gain or loss on the derivative instrument designated and qualifying as a fair value hedge, as well as the offsetting loss or gain on the hedged item attributable to the hedged risk, is recognized in cost of sales on the statement of operations.

(i) Property, Plant and Equipment

Property, plant and equipment, net of salvage value, are depreciated using the straight-line method at rates based on the estimated useful lives for the assets or groups of assets, beginning in the first month of operation following acquisition or completion. The Company capitalizes interest costs associated with major construction projects based on the effective interest rate on aggregate borrowings.

The carrying value of property, plant and equipment includes the fair value of the asset retirement obligation and has been reflected in the balance sheets at cost, net of accumulated depreciation.

Expenditures for major replacements and additions are capitalized. Expenditures for routine refinery repairs and maintenance costs are charged to direct operating expense as incurred. The applicable costs and accumulated depreciation of assets that are sold, retired, or otherwise disposed of are removed from the accounts and the resulting gain or loss is recognized.

(j) Impairment of Long-Lived Assets and Assets to be Disposed Of

Long-lived assets and certain identifiable intangible assets are reviewed for impairment whenever events or changes in circumstances indicate that the carrying amount of such assets may not be recoverable. Recoverability of assets to be held and used is measured by a comparison of the carrying value of an asset to future net cash flows expected to be generated by the asset. If the carrying value of an asset exceeds its expected future cash flows, an impairment loss is recognized based on the excess of the carrying value of the impaired asset over its fair value. These future cash flows and fair values are estimates based on management's judgment and assumptions. Assets to be disposed of are reported at the lower of the carrying amount or fair value less costs of disposition.

(k) Asset Retirement Obligations

The accounting standards established for asset retirement obligations apply to legal obligations associated with the retirement of long-lived assets that result from the acquisition, construction, development and/or normal operation of a long-

F-9

ALON REFINING KROTZ SPRINGS, INC.

NOTES TO FINANCIAL STATEMENTS — (Continued)

(dollars in thousands, except as noted)

lived asset and requires companies to recognize a liability for the fair value of a legal obligation to perform asset retirement activities that are conditional on a future event, if the amount can be reasonably estimated (Note 10).

(l) Turnarounds and Chemical Catalysts Costs

The Company records the cost of planned major refinery maintenance, referred to as turnarounds, and chemical catalyst used in the refinery process units, which are typically replaced in conjunction with planned turnarounds, in “Other assets” in the balance sheets. Turnaround and catalyst costs are currently deferred and amortized on a straight-line basis beginning the month after the completion of the turnaround and ending immediately prior to the next scheduled turnaround. The amortization of deferred turnaround and chemical catalyst costs are presented in “Depreciation and amortization” in the statements of operations.

(m) Income Taxes

Results of the Company's operations are included in the consolidated U.S. Federal income tax return of Alon USA. For financial reporting purposes, federal tax expense is allocated to the Company as if a separate return was filed.

Income taxes are accounted for under the asset and liability method. Deferred tax assets and liabilities are recognized for the future tax consequences attributable to differences between the financial statement carrying amounts of existing assets and liabilities and their respective tax bases and operating loss and tax credit carry forwards. Deferred tax assets and liabilities are measured using enacted tax rates expected to apply to taxable income in the years in which those temporary differences are expected to be recovered or settled. The effect on deferred tax assets and liabilities of a change in tax rates is recognized in income in the period that includes the enactment date.

(n) Environmental Expenditures

The Company accrues for costs associated with environmental remediation obligations when such costs are probable and can be reasonably estimated. Environmental liabilities represent the estimated costs to investigate and remediate contamination at the Company's properties. This estimate is based on internal and third-party assessments of the extent of the contaminations, the selected remediation technology and review of applicable environmental regulations.

Accruals for estimated costs from environmental remediation obligations generally are recognized no later than completion of the remedial feasibility study. Such accruals are adjusted as further information develops or circumstances change. Costs of future expenditures for environmental remediation obligations are not discounted to their present value unless payments are fixed and determinable. Recoveries of environmental remediation costs from other parties are recorded as assets when the receipt is deemed probable. Estimates are updated to reflect changes in factual information, available technology or applicable laws and regulations.

(o) Other Comprehensive Income

Other comprehensive income consists of gains and losses affecting stockholders' equity that, under United States generally accepted accounting principles, are excluded from net loss, such as gains and losses related to certain derivative instruments. The balance in other comprehensive income, net of tax, reported in the statements of stockholders' equity consists of the fair value of commodity derivative contract adjustments.

(p) Commitments and Contingencies

Liabilities for loss contingencies, arising from claims, assessments, litigation, fines, and penalties and other sources are recorded when it is probable that a liability has been incurred and the amount of the assessment and/or remediation can be reasonably estimated. Legal costs incurred in connection with loss contingencies are expensed as incurred. Recoveries of environmental remediation costs from third parties, which are probable of realization, are separately recorded as assets, and are not offset against the related environmental liability.

(q) Intangible Assets

Intangible assets are assets that lack physical substance (excluding financial assets). Intangible assets with indefinite useful lives are not amortized and intangible assets with finite useful lives are amortized on a straight-line basis over 1 to 40 years. Intangible assets not subject to amortization are tested for impairment annually or more frequently if events or changes in circumstances indicate the asset might be impaired. The Company uses December 31 of each year as the valuation date for annual impairment testing purposes.

F-10

ALON REFINING KROTZ SPRINGS, INC.

NOTES TO FINANCIAL STATEMENTS — (Continued)

(dollars in thousands, except as noted)

(r) New Accounting Standards

In June 2011, the provisions of the Financial Accounting Standards Board ("FASB") Accounting Standards Codification ("ASC") topic 220, Comprehensive Income, were amended to allow an entity the option to present the total of comprehensive income, the components of net income, and the components of other comprehensive income either in a single continuous statement or in two separate but consecutive statements. Under either option, the entity is required to present reclassification adjustments on the face of the financial statements for items that are reclassified from other comprehensive income to net income in the statement where those components are presented. These provisions are effective for the first interim or annual period beginning after December 15, 2011, and are to be applied retrospectively, with early adoption permitted. The adoption of this guidance will not affect the Company's financial position or results of operations because these requirements only affect disclosures.

In December 2011, the provisions of FASB ASC 210, Balance Sheet, were amended to require an entity to disclose information about offsetting and related arrangements to enable users of its financial statements to understand the effect of these arrangements on its financial position. The update retains the existing offsetting requirements and enhances the disclosure requirements to allow investors to better compare financial statements prepared under U.S. GAAP with those prepared under International Financial Reporting Standards. These new revisions are to be applied retrospectively and will be effective for interim and annual periods beginning January 1, 2013. The adoption of this guidance will not affect Alon's financial position or results of operations because these requirements will only affect the presentation of the financial statements and disclosures.

(3) Operating Results and Liquidity

The Company's primary sources of liquidity are cash generated from our operating activities, inventory supply and offtake arrangements, other credit lines and additional funding from Alon USA. Future operating results will depend on market factors, primarily the difference between the prices the Company receives from customers for produced products compared to the prices the Company pays to suppliers for crude oil. The Company plans to continue to operate the refinery at current or higher utilization rates as long as the refinery is able to generate cash operating margin. Management believes its current liquidity from the above described sources is adequate to operate the refinery.

The Company's refinery average throughput was 67,877 bpd for the year ended December 31, 2012. In 2012, the Company began processing West Texas Intermediate priced crude oil, which historically is a cheaper priced crude oil compared to the Light Louisiana Sweet crude oil typically processed at the refinery. Cash flow from operating activities for the year ended December 31, 2012 was $18,887.

(4) Supply and Offtake Agreement

Supply and Offtake Agreement with J. Aron & Company

The Company entered into a Supply and Offtake Agreement (the “Supply and Offtake Agreement”) with J. Aron & Company (“J. Aron”). Pursuant to the Supply and Offtake Agreement, (i) J. Aron agreed to sell to the Company, and the Company agreed to buy from J. Aron, at market price, crude oil for processing at the refinery and (ii) the Company agreed to sell, and J. Aron agreed to buy, at market price, certain refined products produced at the refinery.

In connection with the execution of the Supply and Offtake Agreement, the Company also entered into agreements that provided for the sale, at market prices, of the Company's crude oil and certain refined product inventories to J. Aron, the lease to J. Aron of crude oil and refined product storage tanks located at our refinery, and an agreement to identify prospective purchasers of refined products on J. Aron's behalf. The Supply and Offtake Agreement, as amended, has an initial term that expires in May 2018. J. Aron may elect to terminate the agreement prior to the initial term beginning in May 2015 and upon each anniversary thereof, provided the Company receives notice of termination at least six months prior to that date. The Company may elect to terminate in May 2017, provided the Company gives notice of termination at least six months prior to that date.

In February 2013, the Supply and Offtake Agreement was further amended and has an initial term that expires in May 2019. J. Aron may elect to terminate the agreement prior to the initial term in May 2016 and upon each anniversary thereof provided the Company receives notice of termination at least six months prior to that date. The Company may elect to terminate the agreement in May 2018, provided the Company gives notice of termination at least six months prior to that date.

Following expiration or termination of the Supply and Offtake Agreement, the Company is obligated to purchase the crude oil and refined product inventories then owned by J. Aron and located at our refinery.

F-11

ALON REFINING KROTZ SPRINGS, INC.

NOTES TO FINANCIAL STATEMENTS — (Continued)

(dollars in thousands, except as noted)

At December 31, 2012 and 2011, the Company had net current payables to J. Aron for purchases of $27,750 and $12,570, respectively, and other non-current liabilities related to the original financing of $28,016 and $32,778, respectively, and a consignment receivable representing a deposit paid to J. Aron of $6,206 and $6,206, respectively.

Standby LC Facility

In association with the Supply and Offtake Agreement, the Company entered into a secured Credit Agreement (the “Standby LC Facility”) by and between the Company, as Borrower, and Goldman Sachs Bank USA, as Issuing Bank. The Standby LC Facility provides for up to $200,000 of letters of credit to be issued to J. Aron. Obligations under the Standby LC Facility are secured by a first priority lien on the existing and future accounts receivable and inventory of the Company. At this time there is no further availability under the Standby LC Facility.

The Standby LC Facility includes customary events of default and restrictions on the activities of the Company and its subsidiaries. The Standby LC Facility contains no maintenance financial covenants.

(5) Fair Value of Financial Instruments

The carrying amounts of the Company’s cash and cash equivalents, receivables, payables and accrued liabilities approximate fair value due to the short-term maturities of these assets and liabilities. The reported amounts of long-term debt approximate fair value. Derivative financial instruments are carried at fair value, which is based on quoted market prices.

The Company must determine fair value as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date. As required, the Company utilizes valuation techniques that maximize the use of observable inputs (levels 1 and 2) and minimize the use of unobservable inputs (level 3) within the fair value hierarchy. The Company generally applies the “market approach” to determine fair value. This method uses pricing and other information generated by market transactions for identical or comparable assets and liabilities. Assets and liabilities are classified within the fair value hierarchy based on the lowest level (least observable) input that is significant to the measurement in its entirety.

The following table sets forth the assets and liabilities measured at fair value on a recurring basis, by input level, in the balance sheets at December 31, 2012 and 2011:

	Quoted Prices in Active Markets For Identical Assets or Liabilities (Level 1)		Significant Other Observable Inputs (Level 2)			Significant Unobservable Inputs (Level 3)		Total
As of December 31, 2012
Assets:
Commodity contracts (futures and forwards)	$	386	$	—		$	—	$	386
Commodity contracts (swaps)	—		1,514			—		1,514
Liabilities:
Fair value hedge	—		(346		)	—		(346		)
As of December 31, 2011
Assets:
Commodity contracts (swaps)	$	—	$	31,936		$	—	$	31,936
Liabilities:
Commodity contracts (futures and forwards)	72		—			—		72
Commodity contracts (call options)	—		9,268			—		9,268

(6) Derivative Financial Instruments

Mark-to-Market

The Company selectively utilizes commodity derivatives to manage its exposure to commodity price fluctuations and uses crude oil and refined product commodity derivative contracts to reduce risk associated with potential price changes on committed obligations. The Company does not speculate using derivative instruments. Credit risk on the Company’s derivative instruments is mitigated by transacting with counterparties meeting established collateral and credit criteria.

F-12

ALON REFINING KROTZ SPRINGS, INC.

NOTES TO FINANCIAL STATEMENTS — (Continued)

(dollars in thousands, except as noted)

Fair Value Hedges

Fair value hedges are used to hedge price volatility in certain refining inventories and firm commitments to purchase inventories. The level of activity for our fair value hedges is based on the level of our operating inventories. The gain or loss on a derivative instrument designated and qualifying as a fair value hedge, as well as the offsetting loss or gain on the hedged item attributable to the hedged risk, is recognized currently in income in the same period.

As of December 31, 2012, the Company has accounted for certain commodity contracts as fair value hedges with contract purchase volumes of 352 thousand barrels of crude oil with remaining contract terms through May 2018.

Cash Flow Hedges

To designate a derivative as a cash flow hedge, the Company documents at the inception of the hedge the assessment that the derivative will be highly effective in offsetting expected changes in cash flows from the item hedged. This assessment, which is updated at least quarterly, is generally based on the most recent relevant historical correlation between the derivative and the item hedged. If, during the term of the derivative, the hedge is determined to be no longer highly effective, hedge accounting is prospectively discontinued and any remaining unrealized gains or losses, based on the effective portion of the derivative at that date, are reclassified to earnings when the underlying transaction occurs.

As of December 31, 2012, the Company has accounted for certain commodity swap contracts as cash flow hedges with total contract purchase volumes of 5,760 thousand barrels of crude and contract sales volumes 5,760 thousand barrels of refined products with a remaining contract term of twelve months. During the year ended December 31, 2012, the Company recognized unrealized gains of $1,514 related to these transactions in Other Comprehensive Income ("OCI"). There were no amounts reclassified from OCI into cost of sales as a result of the discontinuance of cash flow hedge accounting.

In May 2008, as part of financing the acquisition of the refinery, the Company entered into futures contracts for the forward purchase of crude oil and the forward sale of heating oil of 14,850 thousand barrels. These futures contracts were designated as cash flow hedges for accounting purposes. In the fourth quarter of 2008, the Company determined during its retrospective assessment of hedge effectiveness that the hedge was no longer highly effective. Cash flow hedge accounting was discontinued in the fourth quarter of 2008 and all changes in value subsequent to the discontinuance were recognized into earnings. An after-tax loss of $7,240 was reclassified from equity to earnings for the year ended December 31, 2010.

For the years ended December 31, 2012 and 2011, there was no hedge ineffectiveness recognized in income. No component of the derivative instruments’ gains or losses was excluded from the assessment of hedge effectiveness.

The following table presents the effect of derivative instruments on the statements of financial position.

	As of December 31, 2012
	Asset Derivatives			Liability Derivatives
	Balance Sheet			Balance Sheet
	Location	Fair Value		Location	Fair Value
Derivatives not designated as hedging instruments:
Commodity contracts (futures and forwards)	Accounts receivable	$	386		$	—
Total derivatives not designated as hedging instruments		$	386		$	—
Derivatives designated as hedging instruments:
Commodity contracts (swaps)	Accounts receivable	$	2,287	Accrued liabilities	$	(773	)
Fair value hedge		—		Other non-current liabilities	(346		)
Total derivatives designated as hedging instruments		$	2,287		$	(1,119	)
Total derivatives		$	2,673		$	(1,119	)

F-13

ALON REFINING KROTZ SPRINGS, INC.

NOTES TO FINANCIAL STATEMENTS — (Continued)

(dollars in thousands, except as noted)

	As of December 31, 2011
	Asset Derivatives			Liability Derivatives
	Balance Sheet			Balance Sheet
	Location	Fair Value		Location	Fair Value
Derivatives not designated as hedging instruments:
Commodity contracts (swaps)	Accounts receivable	$	32,678	Accounts payable	$	(742	)
Commodity contracts (call options)		—		Accrued liabilities	(9,268		)
Commodity contracts (futures and forwards)	Accounts receivable	463		Accrued liabilities	(535		)
Total derivatives not designated as hedging instruments		$	33,141		$	(10,545	)

The following tables present the effect of derivative instruments on the Company’s statements of operations and accumulated other comprehensive income (“OCI”).

Cash Flow Hedging Relationships	Gain (Loss) Recognized in OCI		Gain (Loss) Reclassified from Accumulated OCI into Income (Effective Portion)				Gain (Loss) Reclassified from Accumulated OCI into Income (Ineffective Portion and Amount Excluded from Effectiveness Testing)
			Location	Amount			Location	Amount
For the Year Ended December 31, 2012
Commodity contracts (swaps)	$	1,514	Gains (losses) on commodity swaps	$	(68,832	)		$	—
Total derivatives	$	1,514		$	(68,832	)		$	—
For the Year Ended December 31, 2010
Commodity contracts (swaps)	$	—	Gains (losses) on commodity swaps	$	(7,240	)		$	—
Total derivatives	$	—		$	(7,240	)		$	—

Derivatives in fair value hedging relationships:

		Gain (Loss) Recognized in Income
		Year Ended December 31,
	Location	2012			2011		2010
Fair value hedge	Cost of sales	$	(346	)	$	—	$	—
Total derivatives		$	(346	)	$	—	$	—

Derivatives not designated as hedging instruments:

		Gain (Loss) Recognized in Income
		Year Ended December 31,
	Location	2012			2011			2010
Commodity contracts (futures & forwards)	Cost of sales	$	4,431		$	10,837		$	4,246
Commodity contracts (swaps)	Gains (losses) on commodity swaps	(47,188		)	30,040			(597		)
Commodity contracts (call options)	Other loss, net	(7,297		)	(36,280		)	(4,119		)
Total derivatives		$	(50,054	)	$	4,597		$	(470	)

F-14

ALON REFINING KROTZ SPRINGS, INC.

NOTES TO FINANCIAL STATEMENTS — (Continued)

(dollars in thousands, except as noted)

(7) Accounts Receivable

Financial instruments that potentially subject the Company to concentration of credit risk consist primarily of trade accounts receivables and commodity derivative contracts. Credit risk is minimized as a result of the credit quality of the Company's customer base. The Company performs ongoing credit evaluations of its customers and requires letters of credit, prepayments or other collateral or guarantees as management deems appropriate. Valero Energy Corporation ("Valero") and J. Aron accounted for substantially all the Company's net sales for the year ended December 31, 2012. The Company's allowance for doubtful accounts is reflected as a reduction of accounts receivable in the balance sheets. The balance in the allowance account was zero at December 31, 2012 and 2011.

As part of the Supply and Offtake Agreement, there is a net out arrangement. Additionally, product sales to parties other than J. Aron are primarily collected when the sale occurs. As a result of these arrangements, the Company has minimal trade accounts receivable balances at December 31, 2012 and 2011.

(8) Inventories

The Company’s inventories (including inventory consigned to others) are stated at the lower of cost or market. Cost is determined under the last-in, first-out (LIFO) method for crude oil (including inventory consigned to others), refined products, and blendstock inventories. Materials and supplies are stated at average cost.

Carrying value of inventories consisted of the following:

	As of December 31,
	2012		2011
Crude oil, refined products and blendstocks	$	12,268	$	6,023
Crude oil inventory consigned to others (Note 4)	29,656		29,531
Materials and supplies	2,872		2,803
Total inventories	$	44,796	$	38,357

Market values of crude oil, refined products and blendstock inventories exceeded LIFO costs by $14,013 and $18,362 at December 31, 2012 and 2011, respectively.

The Company recorded liabilities associated with consigned inventory of $28,016 and $32,778 in other non-current liabilities at December 31, 2012 and 2011, respectively.

(9) Property, Plant and Equipment, Net

Property, plant and equipment consisted of the following:

	As of December 31,
	2012			2011
Refining facilities	$	429,531		$	415,696
Less accumulated depreciation	(86,210		)	(66,613		)
Property, plant and equipment, net	$	343,321		$	349,083

The useful lives of refining facilities used to determine depreciation expense were 3 - 20 years with an average life of 18 years.

The Company capitalized interest of $1,574, $555 and $498 for the years ended December 31, 2012, 2011 and 2010, respectively. Depreciation expense for the years ended December 31, 2012, 2011 and 2010 was $20,261, $19,899 and $19,538, respectively.

F-15

ALON REFINING KROTZ SPRINGS, INC.

NOTES TO FINANCIAL STATEMENTS — (Continued)

(dollars in thousands, except as noted)

(10) Additional Financial Information

The tables that follow provide additional financial information related to the financial statements.

(a) Other Assets

	As of December 31,
	2012		2011
Deferred turnaround and chemical catalyst cost	$	9,251	$	11,666
Deferred debt issuance costs	4,885		7,131
Intangible assets	2,026		2,069
Long-term receivables	6,206		6,206
Total other assets	$	22,368	$	27,072

(b) Accrued Liabilities, Other Non-Current Liabilities and Accounts Payable

	As of December 31,
	2012		2011
Accrued Liabilities:
Taxes other than income taxes, primarily excise taxes	$	1,670	$	1,519
Employee costs	1,460		1,257
Commodity contracts	773		10,545
Accrued finance charges	7,439		6,839
Other	1,157		1,039
Total accrued liabilities	$	12,499	$	21,199
Other Non-Current Liabilities:
Environmental accrual	$	319	$	356
Asset retirement obligations	1,101		1,029
Consignment inventory	28,016		32,778
Total other non-current liabilities	$	29,436	$	34,163

Accounts payable includes related parties balance of $294,060 and $214,608 at December 31, 2012 and 2011, respectively.

The Company has asset retirement obligations with respect to its refinery due to various legal obligations to clean and/or dispose of these assets at the time they are retired. However, the majority of these assets can be used for extended and indeterminate periods of time provided that they are properly maintained and/or upgraded. It is the Company's practice and intent to continue to maintain these assets and make improvements based on technological advances. When a date or range of dates can reasonably be estimated for the retirement of these assets or any component part of these assets, the Company will estimate the cost of performing the retirement activities and record a liability for the fair value of that cost using established present value techniques.

(11) Income Taxes

Results of the Company's operations are included in the consolidated U.S. Federal income tax return of Alon USA. For financial reporting purposes, federal tax expense is allocated to the Company as if a separate return was filed. The amounts presented below were calculated as if the Company filed separate federal and state income tax returns. The Company had no unrecognized tax benefits as of December 31, 2012.

F-16

ALON REFINING KROTZ SPRINGS, INC.

NOTES TO FINANCIAL STATEMENTS — (Continued)

(dollars in thousands, except as noted)

A reconciliation between the income tax benefit computed on pretax loss at the statutory federal rate and the actual provision for income tax benefit is as follows:

	December 31,
	2012			2011			2010
Computed tax benefit	$	(31,986	)	$	(30,615	)	$	(40,032	)
State and local income taxes, net of federal benefit	(1,444		)	(3,130		)	(3,260		)
Other, net	836			1,005			(307		)
Change in valuation allowance	32,594			32,740			43,599
Income tax benefit	$	—		$	—		$	—

The following table sets forth the tax effects of temporary differences that give rise to significant portions of the deferred tax assets and deferred tax liabilities:

	December 31,
	2012			2011
Deferred income tax assets:
Accrued liabilities and other	$	482		$	505
Non-current accrued liabilities and other	2,506			3,312
Net operating loss carryover	191,626			166,574
Deferred income tax assets	194,614			170,391
Less valuation allowance	(130,293		)	(97,699		)
Net deferred income tax assets	$	64,321		$	72,692
Deferred income tax liabilities:
Unrealized gains	$	(92	)	$	(9,728	)
Property, plant and equipment	(60,489		)	(57,848		)
Other non-current	(2,997		)	(4,291		)
Intangibles	(743		)	(825		)
Deferred income tax liabilities	$	(64,321	)	$	(72,692	)
Net deferred income tax after valuation allowance	$	—		$	—

In assessing the realizability of deferred tax assets, management considers whether it is more likely than not that some portion or all of the deferred tax assets will not be realized. The ultimate realization of deferred tax assets is dependent upon the generation of future taxable income during the periods in which those temporary differences become deductible. Management considers the scheduled reversal of deferred tax liabilities, projected future taxable income, and tax planning strategies in making this assessment. Based upon the level of taxable income and projections for future taxable income, over the periods which the deferred tax assets are deductible, management believes it is more likely than not that the Company will realize the benefits of these deductible differences, net of the existing valuation allowance at December 31, 2012.

The Company performed a review of its tax positions in accordance with ASC Subtopic 740-10, Income Taxes, and determined it has no unrecognized tax benefits. In accordance with ASC Subtopic 740-10, the Company has elected to recognize interest expense related to the underpayment of income taxes in interest expense, and penalties relating to underpayment of income taxes as a reduction to other loss, net, in the statements of operations.

(12) Related Party Transactions

Since the acquisition of our refinery from Valero, the Company has received equity contributions in the amount of $167,656 from Alon Israel Oil Company, Ltd. (“Alon Israel”), the majority stockholder of Alon USA, and Alon USA and its affiliates. The most recent contributions were $41,000 received from Alon USA in 2010.

In addition to the equity contributions, the Company has received letters of credit from both Alon Israel and Alon USA and its affiliates to support the operations of the Company. The amount of letters of credit available during 2012 was $15,000. On December 31, 2012, the Company returned $12,500 of letters of credit to Alon Israel, leaving $2,500 letters of credit

F-17

ALON REFINING KROTZ SPRINGS, INC.

NOTES TO FINANCIAL STATEMENTS — (Continued)

(dollars in thousands, except as noted)

outstanding. For the years endedDecember 31, 2012, 2011 and 2010, the Company recorded interest expense related to these letters of credit of $600, $600 and $1,189, respectively.

The Company is a subsidiary of Alon USA and is operated as a component of the integrated operations of Alon USA and its other subsidiaries. As such, the executive officers of Alon USA, who are employed by another subsidiary of Alon USA, also serve as executive officers of the Company and Alon USA's other subsidiaries and Alon USA performs general corporate and administrative services and functions for the Company and Alon USA's other subsidiaries, which include accounting, treasury, cash management, tax, information technology, insurance administration and claims processing, legal, environmental, risk management, audit, payroll and employee benefit processing, and internal audit services. Alon USA allocates the expenses actually incurred by it in performing these services to the Company and to its other subsidiaries based primarily on the amount of time the individuals performing such services devote to the Company's business and affairs relative to the amount of time they devote to the business and affairs of Alon USA's other subsidiaries. The Company records the amount of such allocations to its financial statements as selling, general and administrative expenses. For the years endedDecember 31, 2012, 2011 and 2010, the Company recorded selling, general and administrative expenses of $7,828, $6,827 and $6,890, respectively, with respect to allocations from Alon USA for such services.

Alon USA currently owns all of the Company's outstanding voting capital stock. As a result, Alon USA can control the election of the Company's directors, exercise control or significant influence over the Company's corporate and management policies and generally determine the outcome of any corporate transaction or other matter submitted to the Company's stockholders for approval, including potential mergers or acquisitions, asset sales and other significant corporate transactions. So long as Alon USA continues to own a majority of the outstanding shares of the Company's voting capital stock, Alon USA will continue to be able to effectively control or influence the outcome of such matters.

(13) Long-Term Debt

Long-term debt consisted of the following:

	As of December 31,
	2012		2011
Senior secured notes, net of discount	$	211,573	$	209,324

(a) Senior Secured Notes

In October 2009, the Company issued 13.50% senior secured notes (the “Senior Secured Notes”) in aggregate principal amount of $216,500 in a private offering. In February 2010, the Company exchanged $216,480 of Senior Secured Notes for an equivalent amount of Senior Secured Notes (“Exchange Notes”) registered under the Securities Act of 1933. The Exchange Notes will mature on October 15, 2014 and the entire principal amount is due at maturity. Interest is payable semi-annually in arrears on April 15 and October 15. The Exchange Notes are substantially identical to the Senior Secured Notes, except that the Exchange Notes have been registered with the Securities and Exchange Commission and are not subject to transfer restrictions. The Senior Secured Notes were issued at an offering price of 94.857% and the Company received gross proceeds of $205,365 (before fees and expenses related to the offering). The Company used the proceeds to repay in full all outstanding obligations under its term loan at that time. The remaining proceeds from the offering were used for general corporate purposes.

The terms of the Senior Secured Notes are governed by an indenture (the “Indenture”) and the obligations under the Indenture are secured by a first priority lien on the Company's property, plant and equipment and a second priority lien on the Company's cash, accounts receivable and inventory.

The Indenture also contains restrictive covenants such as restrictions on loans, mergers, sales of assets, additional indebtedness and restricted payments. The Indenture does not contain any maintenance financial covenants.

The Company is utilizing the effective interest method to amortize the original issue discount over the life of the Senior Secured Notes.

F-18

ALON REFINING KROTZ SPRINGS, INC.

NOTES TO FINANCIAL STATEMENTS — (Continued)

(dollars in thousands, except as noted)

(b) Maturity of Long-Term Debt

The aggregate scheduled maturities of long-term debt for each of the five years subsequent to December 31, 2012 are as follows:

2013	$	—
2014	211,573
2015	—
2016	—
2017	—
2018 and thereafter	—
Total	$	211,573

(c) Interest and Financing Expense

Interest and financing expense included the following:

	Year Ended December 31,
	2012			2011			2010
Interest expense	$	29,228		$	29,228		$	35,098
Letters of credit and finance charges	12,268			8,314			2,239
Amortization of debt issuance costs	2,246			2,044			2,512
Write-off of debt issuance costs	—			—			6,659
Amortization of original issuance discount	2,249			1,946			1,685
Capitalized interest	(1,574		)	(555		)	(498		)
Total interest expense	$	44,417		$	40,977		$	47,695

(14) Employee Benefit Plans

Employees who work for the Company are included in the various employee benefit plans of Alon USA. These plans include qualified, non-contributory defined benefit retirement plans, defined contribution plans, employee and retiree medical, dental, and life insurance plans, incentive plans (i.e., stock options, restricted stock, and bonuses), and other such benefits. For the purposes of these financial statements, the Company is considered to be participating in multi-employer benefit plans of Alon USA.

The Company's allocated share of Alon USA's employee benefit plan expenses, excluding costs related to the incentive plans was $1,403, $2,024 and $2,244for the years endedDecember 31, 2012, 2011 and 2010, respectively.

Employee benefit plan expenses incurred by the Company are included in direct operating expenses with the related payroll costs.

F-19

ALON REFINING KROTZ SPRINGS, INC.

NOTES TO FINANCIAL STATEMENTS — (Continued)

(dollars in thousands, except as noted)

(15) Commitments and Contingencies

(a) Leases

The Company has long-term lease commitments for land, buildings and equipment. In most cases, the Company expects that in the normal course of business, its leases will be renewed or replaced by other leases. The Company has commitments under long-term operating leases for certain land, buildings and equipment expiring at various dates over the next 15 years. Certain long-term operating leases relating to buildings and land include options to renew for additional periods. At December 31, 2012, minimum lease payments on operating leases were as follows:

Year ending December 31:
2013	$	410
2014	410
2015	350
2016	301
2017	301
2018 and thereafter	657
Total	$	2,429

Total rental expense was $3,144, $3,475 and $3,451for the years endedDecember 31, 2012, 2011 and 2010, respectively. Contingent rentals and subleases were not significant.

(b) Other Commitments

In the normal course of business, the Company has long-term commitments to purchase, at market prices, utilities such as natural gas, electricity and water for use by the refinery. The Company is also party to various refined product and crude oil supply and exchange agreements. These agreements are typically short-term in nature or provide terms for cancellation.

Offtake Agreement with Valero

The Company and Valero have an offtake agreement that provides for Valero to purchase, at market prices, light cycle oil and high-sulfur distillate blendstock through July 2013.

(c) Environmental

The Company is subject to loss contingencies pursuant to federal, state, and local environmental laws and regulations. These rules regulate the discharge of materials into the environment and may require the Company to incur future obligations to investigate the effects of the release or disposal of certain petroleum, chemical, and mineral substances at various sites; to remediate or restore these sites; to compensate others for damage to property and natural resources and for remediation and restoration costs. These possible obligations relate to sites owned by the Company and are associated with past or present operations. The Company is currently participating in environmental investigations, assessments and cleanups under these regulations at its refinery. The Company may in the future 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 the Company’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 years. The level of future expenditures for environmental remediation obligations cannot be determined with any degree of reliability.

The Company has accrued a non-current liability for environmental remediation obligations of $319 and $356 at December 31, 2012 and 2011, respectively.

(d) Litigation Matters

The Company is a party to claims and legal proceedings arising in the ordinary course of business. Management believes that there is only a remote likelihood that future costs related to known contingent liabilities related to these legal proceedings would have a material adverse impact on the Company’s results of operations or financial position.

F-20

EXHIBITS

Exhibit No.	Description
3.1	Certificate of Incorporation of Alon Refining Krotz Springs, Inc., as amended by the Certificate of Amendment to Certificate of Incorporation of Alon Refining Krotz Springs, Inc. (incorporated by reference to Exhibit 3.1 to Form S-4, filed by Alon Refining Krotz Springs, Inc. on December 22, 2009, SEC File No. 333-163942).
3.2	Amended and Restated Bylaws of Alon Refining Krotz Springs, Inc. (incorporated by reference to Exhibit 3.2 to Form S-4, filed by Alon Refining Krotz Springs, Inc. on December 22, 2009, SEC File No. 333-163942).
4.1	Indenture, dated as of October 22, 2009, by and among Alon Refining Krotz Springs, Inc. and Wilmington Trust FSB, as Trustee (incorporated by reference to Exhibit 4.1 to Form 8-K, filed by Alon USA Energy, Inc. on October 23, 2009, SEC File No. 001-32567).
10.1	Stock Purchase Agreement, dated May 7, 2008, between Valero Refining and Marketing Company and Alon Refining Krotz Springs, Inc. (incorporated by reference to Exhibit 10.1 to Form 8-K, filed by Alon USA Energy, Inc. on May 13, 2008, SEC File No. 001-32567).
10.2	First Amendment to Stock Purchase Agreement, dated as of July 3, 2008, by and among Valero Refining and Marketing Company, Alon Refining Krotz Springs, Inc. and Valero Refining Company-Louisiana (incorporated by reference to Exhibit 10.1 to Form 8-K, filed by Alon USA Energy, Inc. on July 10, 2008, SEC File No. 001-32567).
10.3	Registration Rights Agreement, dated October 22, 2009, between Alon Refining Krotz Springs, Inc. and Jefferies & Company, Inc. (incorporated by reference to Exhibit 10.2 to Form 8-K, filed by Alon USA Energy, Inc. on October 23, 2009, SEC File No. 001-32567).
10.4	Purchase Agreement, dated October 13, 2009, between Alon Refining Krotz Springs, Inc. and Jefferies & Co. (incorporated by reference to Exhibit 10.1 to Form 8-K, filed by Alon USA Energy, Inc. on October 19, 2009, SEC File No. 001-32567).
10.5†	Offtake Agreement, dated as of July 3, 2008, by and between Valero Marketing and Supply Company and Alon Refining Krotz Springs, Inc. (incorporated by reference to Exhibit 10.5 to Form S-4/A, filed by Alon Refining Krotz Springs, Inc. on January 12, 2010, SEC File No. 333-163942).
10.6†	Earnout Agreement, dated as of July 3, 2008, by and between Valero Refining and Marketing Company and Alon Refining Krotz Springs, Inc. (incorporated by reference to Exhibit 10.6 to Form S-4/A, filed by Alon Refining Krotz Springs, Inc. on January 12, 2010, SEC File No. 333-163942).
10.7†	First Amendment to Earnout Agreement, dated as of August 27, 2009, by and between Valero Refining and Marketing Company and Alon Refining Krotz Springs, Inc. (incorporated by reference to Exhibit 10.7 to Form S-4/A, filed by Alon Refining Krotz Springs, Inc. on January 12, 2010, SEC File No. 333-163942).
10.8*	Executive Employment Agreement, dated as of July 31, 2000, between Jeff D. Morris and Alon USA GP, Inc., as amended by the Amendment to Executive/Management Employment Agreement, dated May 1, 2005 (incorporated by reference to Exhibit 10.23 to Form S-1, filed by Alon USA Energy, Inc. on May 11, 2005, SEC File No. 333-124797).
10.9*	Second Amendment to Executive Employment Agreement, dated as of November 4, 2008, between Jeff D. Morris and Alon USA GP, LLC (incorporated by reference to Exhibit 10.9 to Form 10-Q, filed by Alon USA Energy, Inc. on November 7, 2008, SEC File No. 001-32567).
10.10*	Executive Employment Agreement between Jeff D. Morris and Alon USA Energy, Inc., dated May 3, 2011, (incorporated by reference to Exhibit 10.1 to Form 8-K, filed by Alon USA Energy, Inc. on May 6, 2011, SEC File No. 001-32567).
10.11*	Management Employment Agreement, dated as of March 1, 2010, between Paul Eisman and Alon USA GP, LLC. (incorporated by reference to Exhibit 10.22 to Form 10-K, filed by Alon USA Energy, Inc. on March 15, 2011 SEC File No. 001-32567).
10.12*	Agreement of Principles of Employment, dated as of December 22, 2009, between David Wiessman and Alon USA Energy, Inc. (incorporated by reference to Exhibit 10.44 to Form 10-K, filed by Alon USA Energy, Inc. on March 13, 2012, SEC File No. 001-32567).
10.13*	Amended and Restated Employment Agreement by and between Paramount Petroleum Corporation and Alan P. Moret, dated July 8, 2011 (incorporated by reference to Exhibit 10.1 to Form 8-K, filed by Alon USA Energy, Inc. on July 13, 2011, SEC File No. 001-32567).
10.14*	Executive Employment Agreement, dated as of August 1, 2003, between Shai Even and Alon USA GP, LLC (incorporated by reference to Exhibit 10.49 to Form 10-K, filed by Alon USA Energy, Inc. on March 15, 2007, SEC File No. 001-32567).
10.15*	Amendment to Executive Employment Agreement, dated as of November 4, 2008, between Shai Even and Alon USA GP, LLC. (incorporated by reference to Exhibit 10.14 to Form 10-Q, filed by Alon USA Energy, Inc. on November 7, 2008, SEC File No. 001-32567).

10.16*	Management Employment Agreement, dated as of October 30, 2008, between Michael Oster and Alon USA GP, LLC (incorporated by reference to Exhibit 10.71 to Form 10-K, filed by Alon USA Energy, Inc. on April 10, 2009, SEC File No. 001-32567).
10.17*	Description of Annual Bonus Plans (incorporated by reference to Exhibit 10.2 to Form 10-Q, filed by Alon USA Energy, Inc. on May 6, 2008, SEC File No. 001-32567).
10.18*	Change of Control Incentive Bonus Program (incorporated by reference to Exhibit 10.29 to Form S-1, filed by Alon USA Energy, Inc. on May 11, 2005, SEC File No. 333-124797).
10.19*	Form of Officer Indemnification Agreement (incorporated by reference to Exhibit 10.32 to Form S-1, filed by Alon USA Energy, Inc. on May 11, 2005, SEC File No. 333-124797).
10.20*	Form of Director and Officer Indemnification Agreement (incorporated by reference to Exhibit 10.33 to Form S-1, filed by Alon USA Energy, Inc. on May 11, 2005, SEC File No. 333-124797).
10.21*	Alon USA Energy, Inc. Amended and Restated 2005 Incentive Compensation Plan (incorporated by reference to Exhibit 10.1 to Form 8-K, filed by Alon USA Energy, Inc.  on May 7, 2010, SEC File No. 001-32567).
10.22*	Form of Restricted Stock Award Agreement relating to Director Grants pursuant to Section 12 of the Alon USA Energy, Inc. 2005 Incentive Compensation Plan (incorporated by reference to Exhibit 10.1 to Form 8-K, filed by Alon USA Energy, Inc. on August 5, 2005, SEC File No. 001-32567).
10.23*	Form of Restricted Stock Award Agreement relating to Participant Grants pursuant to Section 8 of the Alon USA Energy, Inc. 2005 Incentive Compensation Plan (incorporated by reference to Exhibit 10.1 to Form 8-K, filed by Alon USA Energy, Inc. on August 23, 2005, SEC File No. 001-32567).
10.24*	Form II of Restricted Stock Award Agreement relating to Participant Grants pursuant to Section 8 of the Alon USA Energy, Inc. 2005 Incentive Compensation Plan (incorporated by reference to Exhibit 10.3 to Form 8-K, filed by Alon USA Energy, Inc. on November 8, 2005, SEC File No. 001-32567).
10.25*	Form of Appreciation Rights Award Agreement relating to Participant Grants pursuant to Section 7 of the Alon USA Energy, Inc. 2005 Incentive Compensation Plan (incorporated by reference to Exhibit 10.1 to Form 8-K, filed by Alon USA Energy, Inc. on March 12, 2007, SEC File No. 001-32567).
10.26*	Form of Amendment to Appreciation Rights Award Agreement relating to Participant Grants pursuant to Section 7 of the Alon USA Energy, Inc. 2005 Incentive Compensation Plan (incorporated by reference to Exhibit 10.2 to Form 8-K, filed by Alon USA Energy, Inc. on January 27, 2010, SEC File No. 001-32567).
10.27*	Form II of Appreciation Rights Award Agreement relating to Participant Grants pursuant to Section 7 of the Alon USA Energy, Inc. 2005 Incentive Compensation Plan (incorporated by reference to Exhibit 10.1 to Form 8-K, filed by Alon USA Energy, Inc. on January 27, 2010, SEC File No. 001-32567.
10.28*	Award Agreement between Alon USA Energy, Inc. and Paul Eisman, dated May 5, 2011, (incorporated by reference to Exhibit 10.1 to Form 8-K, filed by Alon USA Energy, Inc. on May 9, 2011, SEC File No. 001-32567).
10.29*	Form of Award Agreement relating to Executive Officer Restricted Stock Grants pursuant to the Alon USA Energy, Inc. 2005 Amended and Restated Incentive Compensation Plan (incorporated by reference to Exhibit 10.2 to Form 8-K, filed by Alon USA Energy, Inc. on May 9, 2011, SEC File No. 001-32567).
10.30	Credit Agreement, dated May 28, 2010, by and between Alon Refining Krotz Springs, Inc. and Goldman Sachs Bank USA, as Issuing Bank (incorporated by reference to Exhibit 10.5 to Form 10-Q, filed by Alon USA Energy, Inc. on August 9, 2010, SEC File No. 333-124797).
10.31	First Amendment, dated as of July 31, 2012, to the Credit Agreement, dated May 28, 2010, by and between Alon Refining Krotz Springs, Inc. and Goldman Sachs Bank USA, as Issuing Bank (incorporated by reference to Exhibit 10.7 to Form 10-Q, filed by Alon USA Energy, Inc., on August 9, 2012, SEC File No. 001-32567).
10.32	Amended and Restated Supply and Offtake Agreement, dated May 26, 2010 by and between Alon Refining Krotz Springs, Inc. and J. Aron & Company (incorporated by reference to Exhibit 10.6 to Form 10-Q, filed by Alon USA Energy, Inc. on August 9, 2010, SEC File No. 333-124797).
10.33	First Amendment to the Supply and Offtake Agreement, dated January 20, 2011, by and between Alon Refining Krotz Springs, Inc. and J. Aron & Company (incorporated by reference to Exhibit 10.2 to Form 10-Q, filed by the Company on May 10, 2011, SEC File No. 001-32567).
10.34	Amended and Restated Second Amendment to the Supply and Offtake Agreement, dated March 1, 2011, by and between Alon Refining Krotz Springs, Inc. and J. Aron & Company (incorporated by reference to Exhibit 10.3 to Form 10-Q, filed by the Company on May 10, 2011, SEC File No. 001-32567).
10.35	Supplemental Agreement to Supply and Offtake Agreement, dated October 31, 2011, between Alon Refining Krotz Springs, Inc. and J. Aron & Company (incorporated by reference to Exhibit 10.1 to Form 10-Q, filed by the Company on November 7, 2011, SEC File No. 001-32567).
10.36	Amendment, dated as of July 20, 2012, to the Amended and Restated Supply and Offtake Agreement, dated May 28, 2010, by and between Alon Refining Krotz Springs, Inc. and J. Aron & Company (incorporated by reference to Exhibit 10.5 to Form 10-Q, filed by Alon USA Energy, Inc., on August 9, 2012, SEC File No. 001-32567).
23.1	Consent of KPMG LLP

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	Certification 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.
101	The following financial information from Alon Refining Krotz Springs, Inc.'s Annual Report on Form 10-K for the year ended December 31, 2012, formatted in XBRL (Extensible Business Reporting Language): (i) Balance Sheets, (ii) Statements of Operations, (iii) Statements of Comprehensive Loss, (iv) Statement of Stockholders' Equity, (v) Statements of Cash Flows and (vi) Notes to Financial Statements.

____________

*	Identifies management contracts and compensatory plans or arrangements.
†	Portions of the exhibit have been omitted pursuant to a request for confidential treatment. The confidential portions have been furnished to the SEC.

SIGNATURES

Pursuant to the requirements of Section 13 or 15(d) of the Securities and Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.

Date:	March 22, 2013	By:	/s/ Paul Eisman
			Paul Eisman
			Chief Executive Officer

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:	March 22, 2013	By:	/s/ David Wiessman
			David Wiessman
			Executive Chairman
Date:	March 22, 2013	By:	/s/ Paul Eisman
			Paul Eisman
			Chief Executive Officer, President and Director
Date:	March 22, 2013	By:	/s/ Shai Even
			Shai Even
			Senior Vice President, Chief Financial Officer and Director
			(Principal Accounting Officer)
Date:	March 22, 2013	By:	/s/ Jeff D. Morris
			Jeff D. Morris
			Director
Date:	March 22, 2013	By:	/s/ Joseph A. Concienne III
			Joseph A. Concienne III
			Director