Alon USA Partners, LP

Disclaimer

Links to third-party websites are provided solely as a convenience to you. By following the link below, you will be taken to an independent web site that is not maintained by Alon. We do not endorse or make any representations as to the accuracy or completeness of any information, product or materials contained in any of these sites. If you decide to access any of the third-party sites linked to our web site, you do so entirely at your own risk.

Investor Center

Press Releases

Alon USA Partners, LP Reports Third Quarter 2017 Results and Declares Quarterly Cash Distribution

Download PDF

On November 8, 2017 announced transaction for Delek US to acquire remaining 18% of ALDW LP units

BRENTWOOD, Tenn., Nov. 08, 2017 (GLOBE NEWSWIRE) -- Alon USA Partners, LP (NYSE:ALDW) (“Alon Partners”) today announced results for the third quarter of 2017. Net income for the third quarter of 2017 was $29.2 million, or $0.47 per unit, compared to net income of $2.1 million, or $0.03 per unit, for the same period last year. Included in the third quarter 2017 results was an approximately $22.0 million, or $0.35  per common unit charge for inventory fair value adjustment entries at Delek US Holdings, Inc. (NYSE:DK) (“Delek US”) related to its acquisition of Alon USA Energy, Inc. on July 1, 2017 that were recorded at Alon Partners through push down accounting.

On November 8, 2017, Delek US and Alon Partners announced the execution of a definitive merger agreement under which Delek US will acquire all of the outstanding Alon Partners common units representing limited partner interests of Alon Partners which Delek US and its affiliates do not already own in an all-stock for common units merger transaction. Delek US and its affiliates currently own approximately 51.0 million common units of Alon Partners, or approximately 81.6 percent of the outstanding units. Under the terms of the merger agreement, the owners of the outstanding common units in Alon Partners that Delek US and its affiliates do not currently own will receive a fixed exchange ratio of 0.49 shares of Delek US common stock for each common unit of Alon Partners.  This implies a 5.0 percent premium to the 30 trading day volume weighted average ratio through and including November 7, 2017, of .4666 and a 2.9 percent premium to the ratio on November 7, 2017, which was the day before the parties announced this transaction. This transaction was approved by all voting members of the board of directors of Alon Partners’ general partner, upon the recommendation from its conflicts committee and by the board of directors of Delek US. This transaction is expected to close in the first quarter 2018 and is subject to customary closing conditions.

Fred Green, Chief Executive Officer of our general partner, commented, “Our third quarter 2017 results benefited from an improvement in our benchmark Gulf Coast crack spread and discounts in Midland-sourced crude oil relative to WTI Cushing. Our operations were unaffected by Hurricane Harvey and during late August and September we remained focused on supplying our customers as the hurricane reduced product supply on the Gulf Coast during that time period.  During the third quarter 2017, we continued to increase the amount of WTI crude oil that we processed and our wholesale business performed well. The combination with Delek US in an all-equity transaction will provide our public unit holders with the opportunity to be a part of a larger, more diverse and growing company.”

On November 8, 2017, the Board of Directors of Alon USA Partners GP, LLC, the general partner of Alon Partners, declared a cash distribution for the third quarter of 2017 of $0.43 per unit payable on November 22, 2017 to common unitholders of record at the close of business on November 13, 2017, based on cash available for distribution of $26.9 million. During the quarter, capital expenditures included $9.2 million to buyout an operating lease, which reduced the distribution by approximately $0.14 per unit.

Effective July 1, 2017, with the completion of the merger between Delek US and Alon USA Energy, Delek US indirectly owns 100% of our General Partner and 81.6% of our limited partner interest. As a result of these transactions, Alon Partners became a consolidated subsidiary of Delek US Holdings, Inc. and elected to apply “push down” accounting which required its assets and liabilities to be adjusted to fair value on the effective date. Due to the application of push-down accounting, Alon Partners’ consolidated financial statements are presented in two distinct periods to indicate the application of two different basis of accounting between the periods presented. The periods prior to the merger effective date, July 1, 2017, are identified as “Predecessor” and the period from July 1, 2017 forward is identified as “Successor”. Because of this change the periods are not directly comparable.

THIRD QUARTER 2017

Refinery operating margin was $12.49 per barrel for the third quarter of 2017, which included approximately $22.0 million, or a $3.43 per barrel  charge for inventory fair value adjustment at Delek US related to its acquisition of Alon USA on July 1, 2017 that were recorded at Alon Partners through push down accounting. Excluding this amount, the operating margin in the third quarter 2017 would have been $15.92 per barrel compared to $9.22 per barrel for the same period in 2016.  

This increase in operating margin was primarily due to a higher Gulf Coast 3/2/1 crack spread, a widening of the WTI Cushing to WTI Midland spread and a stronger wholesale marketing environment, partially offset by a reduced benefit from the contango environment which increased the cost of crude oil. The third quarter 2016 operating margin was negatively affected by costs associated with the reformer generation. Refinery average throughput for the third quarter of 2017 was 69,723 bpd compared to average throughput of 70,063 bpd for the same period in 2016.

The average Gulf Coast 3/2/1 crack spread was $20.16 per barrel for the third quarter of 2017 compared to $13.31 per barrel for the third quarter of 2016. The average WTI Cushing to WTI Midland spread for the third quarter of 2017 was $0.79 per barrel compared to $0.31 per barrel for the third quarter of 2016. The average WTI Cushing to WTS spread for the third quarter of 2017 was $0.97 per barrel compared to $1.47 per barrel for the third quarter of 2016. The average Brent to WTI Cushing spread for the third quarter of 2017 was $4.04 per barrel compared to $2.05 per barrel for the same period in 2016. The contango environment in the third quarter of 2017 created an average cost of crude benefit of $0.24 per barrel compared to an average cost of crude benefit of $0.84 per barrel for the same period in 2016. The average RINs cost effect on refinery operating margin was $1.14 per barrel in the third quarter of 2017, compared to $0.58 per barrel for the same period in 2016.

Third Quarter 2017 Results | Conference Call Information

Alon Partners has scheduled a conference call, which will be broadcast live over the Internet on Thursday, November 9, 2017 at 7:30 a.m. Central Time, to discuss the third quarter 2017 financial results.  Investors may listen to the conference live by logging on to the Alon Partners website at www.alonpartners.com. A telephonic replay of the conference call will be available through February 9, 2017 and may be accessed by calling 855-859-2056 and using the passcode 99812665. A webcast archive will also be available at www.alonpartners.com shortly after the call and will be accessible for approximately 90 days.

Tax Considerations

This release serves as qualified notice to nominees under Treasury Regulation Section 1.1446-4(b). Please note that 100% of Alon Partners’ distributions to foreign investors are attributable to income that is effectively connected with a United States trade or business. Accordingly, all of Alon Partners’ distributions to foreign investors are subject to federal income tax withholding at the highest effective tax rate for individuals or corporations, as applicable. Nominees, and not Alon Partners, are treated as the withholding agents responsible for withholding on the distributions received by them on behalf of foreign investors.

Safe Harbor Provisions Regarding Forward-Looking Statements

Any statements in this release that are not statements of historical fact are 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. These forward-looking statements include, but are not limited to, statements regarding the potential merger between Alon Partners and Delek US including the closing, timeline and benefits relating thereto; crude oil slates; crude oil and product costs, netbacks and margins; opportunities; anticipated performance and financial position; continued safe and reliable operations; and other factors.  Forward-looking statements should not be read as a guarantee of future performance or results and will not be accurate indications of the times at or by which such performance or results will be achieved.  Forward-looking information is based on information available at the time and/or management's good faith belief with respect to future events, and is subject to risks and uncertainties that could cause actual performance or results to differ materially from those expressed in the statements.  Alon Partners undertakes no obligation to update or revise any such forward-looking statements, except as required by applicable law or regulation.  Additional information regarding these and other risks is contained in our filings with the Securities and Exchange Commission.

About Alon USA Partners, LP

Alon USA Partners, LP is a Delaware limited partnership in which Delek US Holdings, Inc. (NYSE:DK) owns 100% of the general partner and 81.6% of the limited partner interest. Alon Partners owns and operates a crude oil refinery in Big Spring, Texas, with a crude oil throughput capacity of 73,000 barrels per day. Alon Partners refines crude oil into finished products, which are marketed primarily in Central and West Texas, Oklahoma, New Mexico and Arizona through its integrated wholesale distribution network to retail convenience stores owned by Delek US and other third-party distributors.

No Offer or Solicitation
This communication relates to a proposed business combination between Delek US and Alon Partners. This announcement is for informational purposes only and is neither an offer to purchase, nor a solicitation of an offer to sell, any securities or the solicitation of any vote in any jurisdiction pursuant to the proposed transactions or otherwise, nor shall there be any sale, issuance or transfer of securities in any jurisdiction in contravention of applicable law. No offer of securities shall be made except by means of a prospectus meeting the requirements of Section 10 of the Securities Act of 1933, as amended.

Additional Information and Where to Find It
This press release does not constitute an offer to sell or the solicitation of an offer to buy any securities or a solicitation of any vote or approval.

In connection with the proposed acquisition transaction, a registration statement on Form S-4 will be filed with the SEC that will include a consent statement of Alon Partners. Delek US also plans to file other relevant materials with the SEC. UNITHOLDERS OF ALON PARTNERS ARE ENCOURAGED TO READ THE REGISTRATION STATEMENT AND ANY OTHER RELEVANT DOCUMENTS FILED WITH THE SEC, INCLUDING THE CONSENT STATEMENT/PROSPECTUS THAT WILL BE PART OF THE REGISTRATION STATEMENT, BECAUSE THEY WILL CONTAIN IMPORTANT INFORMATION ABOUT THE PROPOSED ACQUISITION. The final consent solicitation /prospectus will be mailed to unitholders of Alon Partners. Investors and security holders will be able to obtain the documents, and any other documents that Delek US has filed with the SEC, free of charge at the SEC's website, www.sec.gov. In addition, documents filed with the SEC by Delek US will be available free of charge by (1) accessing Delek US’ website at www.delekus.com under the "Investor Relations" link and then under the heading "SEC Filings"; (2) writing Delek US at 7102 Commerce Way, Brentwood, TN 37027, Attention: Investor Relations; or (3) writing Alon Partners at 7102 Commerce Way, Brentwood, TN 37027, Attention: Investor Relations.

Participants in the Solicitation
Delek US, Alon Partners and their respective directors and executive officers may be deemed to be participants in the solicitation of consents in favor of the acquisition from the unitholders of Alon Partners. Additional information regarding the interests of those participants and other persons who may be deemed participants in the transaction may be obtained by reading the consent statement/prospectus regarding the proposed acquisition when it becomes available. Free copies of this document may be obtained as described in the preceding paragraph.

 
ALON USA PARTNERS, LP AND SUBSIDIARIES
CONDENSED CONSOLIDATED BALANCE SHEETS (UNAUDITED)
(In thousands, except share and per share data)
 
  Successor     Predecessor
  September 30,
 2017
    December 31,
 2016
ASSETS        
Current assets:        
Cash and cash equivalents $ 268,572       $ 73,524  
Accounts receivables, net 83,781       82,292  
Accounts receivables from related parties       11,425  
Inventories 99,802       49,682  
Prepaid expenses and other current assets 4,877       4,949  
Total current assets 457,032       221,872  
Property, plant and equipment, net 418,106       420,554  
Goodwill 568,541        
Other non-current assets 54,031       53,211  
Total assets $ 1,497,710       $ 695,637  
LIABILITIES AND PARTNERS’ EQUITY        
Current liabilities:        
Accounts payable $ 101,588       $ 249,835  
Accounts payable to related parties, net of related receivables 84,631        
Accrued expenses and other current liabilities 181,820       43,100  
Current portion of long-term debt 2,500       2,500  
Obligation under Supply and Offtake Agreement 99,108        
Total current liabilities 469,647       295,435  
Non-Current Liabilities:        
Other non-current liabilities 27,381       62,880  
Long-term debt, net of current portion 335,625       233,819  
Deferred income tax liability 2,374        
Total non-current liabilities 365,380       296,699  
         
Partners’ equity:        
General Partner        
Common unit interest - 62,529,328 and 62,520,220 units issued and outstanding at September 30, 2017 and December 31, 2016, respectively 662,683       103,503  
Total partners’ equity 662,683       103,503  
Total liabilities and partners’ equity $ 1,497,710       $ 695,637  


ALON USA PARTNERS, LP AND SUBSIDIARIES CONSOLIDATED
EARNINGS RELEASE
 
  Successor     Predecessor
RESULTS OF OPERATIONS - FINANCIAL DATA
(UNAUDITED)
Three Months Ended
September 30, 2017
    Three Months Ended
September 30, 2016
Net sales:        
Affiliate $ 94,536       $ 82,717  
Third party 400,942       379,540  
Net sales 495,478       462,257  
Operating costs and expenses:        
Cost of goods sold 415,386       404,207  
Operating expenses 26,548       25,125  
Selling, general and administrative expenses 7,741       8,153  
Depreciation and amortization 7,620       14,581  
Loss on disposition of assets        
Total operating costs and expenses 457,295       452,066  
Operating income 38,183       10,191  
Interest expense, net 8,817       8,144  
Other expense (income), net 5       (353 )
Total non-operating expense 8,822       7,791  
Income before income tax expense 29,361       2,400  
Income tax expense 125       317  
Net income attributable to partners $ 29,236       $ 2,083  
Comprehensive income attributable to partners $ 29,236       $ 2,083  
Net income per unit - (basic and diluted) $ 0.47       $ 0.03  
Weighted average common units outstanding (in thousands) - (basic and diluted) 62,529       62,520  
Cash distribution per unit $ 0.35       $ 0.14  
CASH FLOW DATA:        
Net cash provided by (used in):        
Operating activities $ 94,574       $ 11,870  
Investing activities (17,738 )     (5,954 )
Financing activities 24,497       36,027  
OTHER DATA:        
Adjusted EBITDA (1) $ 67,798       $ 25,125  
Capital expenditures 12,681       4,499  
Capital expenditures for turnarounds and catalysts       1,455  
Capital expenditure for operating lease purchase $ 9,200       $  
Key Operating Statistics:        
Per barrel of throughput:        
Refinery operating margin (2) $ 12.49       $ 9.22  
Refinery direct operating expense (3) 4.14       3.90  


  Successor     Predecessor   Predecessor
RESULTS OF OPERATIONS - FINANCIAL DATA
(UNAUDITED)
Period from
July 1, 2017 to
September 30, 2017
    Period from
January 1, 2017
to June 30, 2017
  Nine Months
Ended September
30, 2016
Net sales:            
Affiliate $ 94,536       $ 185,760     $ 222,711  
Third party 400,942       880,523     1,076,012  
Net sales 495,478       1,066,283     1,298,723  
Operating costs and expenses:            
Cost of goods sold 415,386       911,366     1,134,275  
Operating expenses 26,548       52,638     73,424  
Selling, general and administrative expenses 7,741       14,156     24,264  
Depreciation and amortization 7,620       28,691     43,454  
Loss on disposition of assets       23      
Total operating costs and expenses 457,295       1,006,874     1,275,417  
Operating income 38,183       59,409     23,306  
Interest expense, net 8,817       16,497     28,651  
Other expense (income), net 5       554     (550 )
Total non-operating expense 8,822       17,051     28,101  
Income (loss) before income tax expense 29,361       42,358     (4,795 )
Income tax expense 125       566     493  
Net income (loss) attributable to partners $ 29,236       $ 41,792     $ (5,288 )
Comprehensive income (loss) attributable to partners $ 29,236       $ 41,792     $ (5,288 )
Net income (loss) per unit - (basic and diluted) $ 0.47       $ 0.67     $ (0.08 )
Weighted average common units outstanding (in thousands) - (basic and diluted) 62,529       62,523     62,515  
Cash distribution per unit $ 0.35       $ 0.49     $ 0.22  
CASH FLOW DATA:            
Net cash provided by (used in):            
Operating activities $ 94,574       $ 77,145     $ 58,457  
Investing activities (17,738 )     (13,191 )   (26,878 )
Financing activities 24,497       29,761     39,231  
OTHER DATA:            
Adjusted EBITDA (1) $ 67,798       $ 87,569     $ 67,310  
Capital expenditures 12,681       12,175     17,199  
Capital expenditures for turnarounds and catalysts       1,016     9,679  
Capital expenditure for operating lease purchase $ 9,200       $     $  
Key Operating Statistics:            
Per barrel of throughput:            
Refinery operating margin (2) $ 12.49       $ 11.47     $ 8.52  
Refinery direct operating expense (3) 4.14       3.86     3.85  


PRICING STATISTICS: For the Three Months
Ended September 30,
  Nine Months
Ended September 30,
  2017   2016   2017     2016
                 
Crack spreads (per barrel):                
Gulf Coast 3/2/1 (4) $ 20.16     $ 13.31     $ 16.20       $ 12.25  
WTI Cushing crude oil (per barrel) $ 48.16     $ 44.88     $ 49.31       $ 41.40  
Crude oil differentials (per barrel):                
WTI Cushing less WTI Midland (5) $ 0.79     $ 0.31     $ 0.53       $ 0.18  
WTI Cushing less WTS (5) 0.97     1.47     1.15       0.82  
Brent less WTI Cushing (5) 4.04     2.05     3.18       1.81  
Product price (dollars per gallon):                
Gulf Coast unleaded gasoline $ 1.63     $ 1.39     $ 1.57       $ 1.29  
Gulf Coast ultra-low sulfur diesel 1.62     1.37     1.55       1.25  
Natural gas (per MMBtu) 2.95     2.79     3.05       2.35  


SALES, THROUGHPUT AND PRODUCTION DATA: For the Three Months Ended   For the Nine Months Ended
September 30,   September 30,
  2017   2016   2017   2016
  bpd   %   bpd   %   bpd   %   bpd   %
Sales                              
                               
Refinery throughput:                              
WTS crude 17,016     24.4     34,292     48.9     21,617     29.5     32,189     46.3  
WTI crude 52,101     74.7     32,503     46.4     49,095     66.9     34,428     49.4  
Blendstocks 606     0.9     3,268     4.7     2,672     3.6     2,969     4.3  
Total refinery throughput (6) 69,722     100.0     70,063     100.0     73,384     100.0     69,586     100.0  
Refinery production:                              
Gasoline 35,990     51.9     33,637     48.1     36,052     49.4     33,826     48.7  
Diesel/jet 27,001     38.9     26,004     37.2     27,912     38.3     25,108     36.1  
Asphalt 1,213     1.7     2,818     4.0     2,036     2.8     2,846     4.1  
Petrochemicals 2,956     4.3     3,861     5.5     3,765     5.2     3,611     5.2  
Other 2,196     3.2     3,661     5.2     3,193     4.4     4,084     5.9  
Total refinery production (7) 69,356     100.0     69,981     100.0     72,958     100.0     69,475     100.0  
Refinery utilization (8)     94.7 %       99.1 %       96.9 %       95.5 %


  Successor     Predecessor
  Three Months
Ended September
30, 2017
    Three Months
Ended September
30, 2016
Reconciliation of Adjusted EBITDA to net income:        
Net income $ 29,236       $ 2,083  
Add:        
Interest Expense 8,817       8,144  
State income tax expense 125       317  
Depreciation and amortization 7,620       14,581  
Inventory fair value adjustment 22,000        
Adjusted EBITDA (1) $ 67,798       $ 25,125  
Maintenance/growth capital expenditures 21,881       4,499  
Turnaround and catalyst replacement capital expenditures       1,455  
Major turnaround reserve for future years (a) 3,500       1,500  
Principal payments 625       625  
Income tax payments 310       317  
Gain (loss) on asset disposals        
Interest paid in cash 8,314       7,337  
Cash available for distribution before special expenses 33,168       9,392  
Special reserve for cost increase in capital expenditures associated with the consent decree (b) 6,300        
Cash available for distribution $ 26,868       $ 9,392  
         


  Successor     Predecessor   Predecessor
  Period from
July 1, 2017 to
September 30, 2017
    Period from
January 1, 2017
to June 30, 2017
  Nine Months
Ended
September 30,
2016
Reconciliation of net income to EBITDA, Adjusted EBITDA (1) and cash available for distribution:            
Net income $ 29,236       41,792     $ (5,288 )
Add:            
Interest Expense 8,817       16,497     28,651  
Income tax expense 125       566     493  
Depreciation and amortization 7,620       28,691     43,454  
Inventory fair value adjustment 22,000            
Adjusted EBITDA (2) $ 67,798       $ 87,546     $ 67,310  
Maintenance/growth capital expenditures 21,881       12,175     17,199  
Turnaround and catalyst replacement capital expenditures       1,016     4,616  
Major turnaround reserve for future years  (a) 3,500       7,000     4,500  
Principal payments 625       1,250     1,875  
Income tax payments 310       566     493  
Less: Gain (loss) on asset disposals       23      
Interest paid in cash 8,314       16,155     27,219  
Cash available for distribution before special expenses 33,168       49,407     11,408  
Special reserve for cost increase in capital expenditures associated with the consent decree (b) 6,300       4,000      
Cash available for distribution $ 26,868       $ 45,407     $ 11,408  
 
  1. Major turnaround reserve for future years was increased from $1,500 in prior quarters to $3,500 in the first quarter of 2017 to reflect an increase in the estimated cost of the next major five-year turnaround from $30,000 to $50,000.

  2. The Partnership is finalizing a consent decree with the U.S. Environmental Protection Agency to reduce air emissions from the Big Spring refinery, which will require additional capital expenditures. The Board of Directors of our general partner has elected to reserve $6.3 million from cash available for distribution each quarter through the fourth quarter of 2018 to cover a $28 million increase in the expected costs.

________________

  1. To supplement our financial information presented in accordance with United States generally accepted accounting principles (“GAAP”), management uses additional measures that are known as “non-GAAP financial measures” in its evaluation of past performance and prospectus for the future. The primary measures used by management are Adjusted EBITDA, Earnings Before Interest, Taxes, Depreciation and Amortization (“EBITDA”) and cash available for distribution.

    EBITDA and Adjusted EBITDA represent earnings before income tax expense, interest expense, depreciation and amortization and in the case of Adjusted EBITDA, the inventory fair value adjustment. Neither EBITDA nor Adjusted EBITDA is a recognized measurement under GAAP; however, the amounts included in EBITDA and Adjusted EBITDA are derived from amounts included in our consolidated financial statements. Our management believes that the presentation of EBITDA and Adjusted EBITDA is useful to investors because it is frequently used by securities analysts, investors, and other interested parties in the evaluation of companies in our industry. In addition, our management believes that EBITDA and Adjusted EBITDA are useful in evaluating our operating performance compared to that of other companies in our industry because the calculation of EBITDA and Adjusted EBITDA generally eliminates the effects of income tax expense, interest expense and the accounting effects of capital expenditures and acquisitions, items that may vary for different companies for reasons unrelated to overall operating performance.

    Cash available for distribution is derived from net income plus or minus all adjustments to arrive at Adjusted EBITDA, less cash needed for maintenance capital expenditures, debt service and other contractual obligations, and reserves for future operating or capital needs that the board of directors of our general partner deems necessary or appropriate, including reserves for our expenses in the quarters in which our planned turnarounds and catalyst replacement occur and special reserve for cost increase in capital expenditures associated with the consent decree.

    We believe that the presentation of EBITDA, Adjusted EBITDA and cash available for distribution provides useful information to investors in assessing our financial condition and results of operations.  EBITDA, Adjusted EBITDA and cash available for distribution should not be considered alternatives to net income, operating income, cash flow from operating activities or any other measure of financial performance or liquidity presented in accordance with U.S. GAAP.  EBITDA, Adjusted EBITDA and cash available for distribution have important limitations as analytical tools because they exclude some but not all items that affect net income and net cash provided by operating activities.  Additionally, because EBITDA, Adjusted EBITDA and cash available for distribution may be defined differently by other companies in our industry, our definition of EBITDA, Adjusted EBITDA and cash available for distribution may not be comparable to similarly titled measures of other companies, thereby diminishing its utility.  Because of these limitations, EBITDA, Adjusted EBITDA and cash available for distribution should not be considered a measure of discretionary cash available to us to invest in the growth of our business. We compensate for these limitations by relying primarily on our GAAP results and using EBITDA, Adjusted EBITDA and cash available for distribution only supplementally.
  1. Refinery operating margin is a per barrel measurement calculated by dividing the margin between net sales and cost of sales (exclusive of certain inventory adjustments) by the refinery’s total throughput. Industry-wide refining results are driven and measured by the margins between refined product prices and the prices for crude oil, which are referred to as crack spreads. We compare our refinery operating margin to these crack spreads to assess our operating performance relative to other participants in our industry.

    Refinery operating margin for the Successor three-month period ended September 30, 2017 and Predecessor six-month period ended June 30, 2017 excludes gains (losses) related to inventory adjustments of $0 and $1,264, respectively. Refinery operating margin for the Predecessor three- and nine-month periods ended September 30, 2016 excludes gains (losses) related to inventory adjustments of $1,419 and $2,046, respectively.
  1. Refinery direct operating expense is a per barrel measurement calculated by dividing direct operating expenses by total throughput.

  2. We compare our refinery operating margin to the Gulf Coast 3/2/1 crack spread. A Gulf Coast 3/2/1 crack spread is calculated assuming that three barrels of WTI Cushing crude oil are converted, or cracked, into two barrels of Gulf Coast conventional gasoline and one barrel of Gulf Coast ultra-low sulfur diesel.

  3. The WTI Cushing less WTI Midland spread represents the differential between the average price per barrel of WTI Cushing crude oil and the average price per barrel of WTI Midland crude oil. The WTI Cushing less WTS, or sweet/sour, spread represents the differential between the average price per barrel of WTI Cushing crude oil and the average price per barrel of WTS crude oil. The Brent less WTI Cushing spread represents the differential between the average price per barrel of Brent crude oil and the average price per barrel of WTI Cushing crude oil.

  4. Total refinery throughput represents the total barrels per day of crude oil and blendstock inputs in the refinery production process.

  5. Total refinery production represents the barrels per day of various refined products produced from processing crude and other refinery feedstocks through the crude units and other conversion units. Effective July 1, 2017, with the completion of the merger between Delek US and Alon USA Energy, Delek US indirectly owns 100% of our General Partner and 81.6% of our limited partner interest. As a result of these transactions, Alon Partners became a consolidated subsidiary of Delek US Holdings, Inc. As a result of throughput and yield methodologies be conformed to Delek US in the third quarter 2017, the current period and prior year periods are not directly comparable.

  6. Refinery utilization represents average daily crude oil throughput divided by crude oil capacity, excluding planned periods of downtime for maintenance and turnarounds.

U.S. Investor / Media Relations Contact:
Keith Johnson
Vice President of Investor Relations
615-435-1366

Source: Alon USA Partners, LP