2014

Alon USA Partners Reports First Quarter Results Partnership schedules conference call for May 9, 2013 at 10:00 a.m. Eastern

DALLAS, May 7, 2013 /PRNewswire/ -- Alon USA Partners, LP (NYSE: ALDW) (the "Partnership") today announced results for the first quarter of 2013. Net income for the first quarter of 2013 was $93.5 million, or $1.50 per unit, compared to $48.1 million for the same period last year.

Paul Eisman, CEO and President of the Partnership's general partner, commented, "Our first quarter results, the first full quarter for our newly formed partnership, proved very successful. We generated adjusted EBITDA of $116 million compared to $70 million for this period last year. Additionally, we just recently announced a cash distribution of $1.48 per unit for a total cash distribution of $92.5 million.

"During the first quarter we operated at reduced refinery throughput rates as we performed maintenance on the crude unit vacuum tower and utilized this time to complete a reformer catalyst regeneration and a diesel hydro-treater catalyst replacement that were scheduled to be performed in the second quarter. We expect throughput to average approximately 72,000 barrels per day for the second quarter."

FIRST QUARTER 2013

Refinery operating margin was $28.76 per barrel for the first quarter of 2013 compared to $15.24 per barrel for the same period in 2012. This increase is due to higher Gulf Coast 3/2/1 crack spreads and a widening of the WTI to WTS spread. The refinery's throughput for the first quarter of 2013 averaged 59,476 barrels per day ("bpd") compared to 69,512 bpd for the same period in 2012. The reduction in throughput was due to the maintenance and catalysts work completed during the first quarter of 2013.

The average Gulf Coast 3/2/1 crack spread was $28.40 per barrel for the first quarter of 2013 compared to $24.78 per barrel for the first quarter of 2012. The average WTI to WTS spread for the first quarter of 2013 was $11.41 per barrel compared to $2.16 per barrel for the same period in 2012.

CONFERENCE CALL

The Partnership has scheduled a conference call which will also be webcast live on Thursday, May 9, 2013 at 10:00 a.m. eastern time (9:00 a.m. central time), to discuss the first quarter 2013 results. To access the call, please dial 800-762-8779 or 480-629-9645, for international callers, at least 10 minutes prior to the start time and ask for the Alon USA Partners, LP call. Investors may also access the live webcast on the Alon Partners website, http://www.alonpartners.com by logging on that site and clicking "Investors." A telephonic replay of the conference call will be available through May 23, 2013, and may be accessed by calling 800-406-7325, or 303-590-3030, for international callers, and using the passcode 4614673#. The archived webcast will also be available at www.alonpartners.com shortly after the call and will be accessible for approximately 90 days. For more information, please contact Donna Washburn at Dennard Lascar Associates at 713-529-6600 or email dwashburn@dennardlascar.com.

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.

Alon USA Partners, LP is a Delaware limited partnership formed in August 2012 by Alon USA Energy, Inc. ("Alon Energy") (NYSE: ALJ). Alon Partners owns and operates a crude oil refinery in Big Spring, Texas with total throughput capacity of approximately 70,000 barrels per day. Alon Partners refines crude oil into finished products, which is marketed primarily in West Texas, Central Texas, Oklahoma, New Mexico and Arizona through its wholesale distribution network to both Alon Energy's retail convenience stores and other third-party distributors.

Contacts:

Claire Hart, Senior Vice President

Alon USA Partners GP, LLC     
972-367-3649




Investors: Jack Lascar/ Sheila Stuewe

Dennard Lascar Associates, LLC 713-529-6600
Media: Blake Lewis

Lewis Public Relations

214-635-3020

Ruth Sheetrit

SMG Public Relations

011-972-547-555551

 

- Tables to follow -


ALON USA PARTNERS, LP AND SUBSIDIARIES CONSOLIDATED

EARNINGS RELEASE




RESULTS OF OPERATIONS - FINANCIAL DATA

(ALL INFORMATION IN THIS PRESS RELEASE EXCEPT FOR BALANCE SHEET DATA AS OF DECEMBER 31, 2012, IS UNAUDITED)

For the Three Months Ended


March 31,


2013



2012





Predecessor (B)


(dollars in thousands, except per unit data)

STATEMENTS OF OPERATIONS DATA: (A)





Net sales (1)

$

804,167




$

884,274


Operating costs and expenses:





Cost of sales

650,203




787,894


Direct operating expenses

30,422




22,670


Selling, general and administrative expenses

7,665




3,845


Depreciation and amortization

12,064




11,966


Total operating costs and expenses

700,354




826,375


Operating income

103,813




57,899


Interest expense

(9,392)




(5,074)


Interest expense - related parties




(4,267)


Other income, net

4




21


Income before state income tax expense

94,425




48,579


State income tax expense

900




503


Net income

$

93,525




$

48,076


Earnings per unit

$

1.50





Weighted average common units outstanding (in thousands)

62,501





CASH FLOW DATA:





Net cash provided by (used in):





Operating activities

$

166,646




$

43,475


Investing activities

(6,719)




(7,281)


Financing activities

(35,456)




(136,181)


OTHER DATA:





Adjusted EBITDA (2)

$

115,881




$

69,886


Capital expenditures

2,941




5,222


Capital expenditures for turnaround and chemical catalyst

3,778




2,059


KEY OPERATING STATISTICS:





Per barrel of throughput:





Refinery operating margin (3)

$

28.76




$

15.24


Refinery direct operating expense (4)

5.68




3.58


PRICING STATISTICS:





Crack spreads (per barrel):





Gulf Coast 3-2-1 (5)

$

28.40




$

24.78


WTI crude oil (per barrel)

$

94.27




$

103.00


Crude oil differentials (per barrel):





WTI less WTS (6)

$

11.41




$

2.16


Product price (dollars per gallon):





Gulf Coast unleaded gasoline

$

2.84




$

2.98


Gulf Coast ultra-low sulfur diesel

3.09




3.16


Natural gas (per MMBtu)

3.48




2.50


 











March 31,
2013


December 31,
2012

BALANCE SHEET DATA (end of period):




Cash and cash equivalents

$

190,472



$

66,001


Working capital

68,564



1,702


Total assets

878,344



763,423


Total debt

295,810



295,311


Total equity

239,625



181,726


 





THROUGHPUT AND PRODUCTION DATA:

For the Three Months Ended

March 31,


2013



2012







Predecessor


bpd


%



bpd


%

Refinery throughput:









WTS crude

45,220



76.0




55,546



79.9


WTI crude

11,549



19.4




12,206



17.6


Blendstocks

2,707



4.6




1,760



2.5


Total refinery throughput (7)

59,476



100.0




69,512



100.0


Refinery production:









Gasoline

29,785



50.4




35,140



50.7


Diesel/jet

19,298



32.6




22,236



32.1


Asphalt

3,359



5.7




4,535



6.6


Petrochemicals

3,726



6.3




4,136



6.0


Other

2,969



5.0




3,187



4.6


Total refinery production (8)

59,137



100.0




69,234



100.0


Refinery utilization (9)



92.4

%





96.8

%

 


(A)

Earnings per unit information is not presented for the three months ended March 31, 2012 as there was no common equity or potential common equity publicly traded during that period and therefore is not required by Financial Accounting Standards Board ("FASB") Accounting Standards Codification ("ASC") topic 260, Earnings per share.



(B)

The information presented contains the unaudited combined financial results of Alon USA Partners, LP Predecessor ("Predecessor"), our predecessor for accounting purposes, for the three months ended March 31, 2012.



(1)

Includes sales to related parties of $141,899 and $150,563 for the three months ended March 31, 2013 and 2012, respectively.



(2)

Adjusted EBITDA represents earnings before state income tax expense, interest expense, depreciation and amortization, and gain on disposition of assets. Adjusted EBITDA is not a recognized measurement under GAAP; however, the amounts included in Adjusted EBITDA are derived from amounts included in our consolidated financial statements. Our management believes that the presentation of Adjusted EBITDA is useful to investors because it is frequently used by securities analysts, investors, and other interested parties in the evaluation of companies in our industry. In addition, our management believes that Adjusted EBITDA is useful in evaluating our operating performance compared to that of other companies in our industry because the calculation of Adjusted EBITDA generally eliminates the effects of state income tax expense, interest expense, gain on disposition of assets and the accounting effects of capital expenditures and acquisitions, items that may vary for different companies for reasons unrelated to overall operating performance.




Adjusted EBITDA has limitations as an analytical tool, and you should not consider it in isolation, or as a substitute for analysis of our results as reported under GAAP. Some of these limitations are:

  • Adjusted EBITDA does not reflect our cash expenditures or future requirements for capital expenditures or contractual commitments;
  • Adjusted EBITDA does not reflect the interest expense or the cash requirements necessary to service interest or principal payments on our debt;
  • Adjusted EBITDA does not reflect changes in or cash requirements for our working capital needs; and
  • Our calculation of Adjusted EBITDA may differ from EBITDA calculations of other companies in our industry, limiting its usefulness as a comparative measure.









Because of these limitations, Adjusted EBITDA should not be considered a measure of discretionary cash available to us to invest in the growth of our business. We compensate for these limitations by relying primarily on our GAAP results and using Adjusted EBITDA only supplementally.



The following table reconciles net income to Adjusted EBITDA for the three months ended March 31, 2013 and 2012, respectively:





For the Three Months Ended


March 31,


2013



2012





Predecessor


(dollars in thousands)

Net income

$

93,525




$

48,076


State income tax expense

900




503


Interest expense

9,392




5,074


Interest expense - related parties




4,267


Depreciation and amortization

12,064




11,966


Adjusted EBITDA

$

115,881




$

69,886




(3)

Refinery operating margin is a per barrel measurement calculated by dividing the margin between net sales and cost of sales by the refinery's throughput volumes. Industry-wide refining results are driven and measured by the margins between refined product prices and the prices for crude oil, which are referred to as crack spreads. We compare our refinery operating margin to these crack spreads to assess our operating performance relative to other participants in our industry.



(4)

Refinery direct operating expense is a per barrel measurement calculated by dividing direct operating expenses by total throughput volumes.



(5)

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



(6)

The WTI/WTS, or sweet/sour, spread represents the differential between the average value per barrel of WTI crude oil and the average value per barrel of WTS crude oil.



(7)

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



(8)

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.



(9)

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

SOURCE Alon USA Partners, LP



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