Alon USA Partners, LP - FORM 8-K - EX-99.1 - PRESS RELEASE - May 4, 2016

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8-K - 8-K - Alon USA Partners, LPaldw2016q1earningsrelease8.htm


 
NEWS RELEASE
 
 
 
 
Contacts:
Stacey Morris, Investor Relations Manager
Alon USA Partners GP, LLC
972-367-3808
FOR IMMEDIATE RELEASE
 
 
 
 
Investors: Jack Lascar
Dennard § Lascar Associates, LLC
713-529-6600

Media: Blake Lewis
Lewis Public Relations
214-635-3020
Alon USA Partners, LP Reports First Quarter 2016 Results

Schedules conference call for May 5, 2016 at 10:00 a.m. Eastern
DALLAS, TEXAS, May 4, 2016 - Alon USA Partners, LP (NYSE: ALDW) (“Alon Partners”) today announced results for the first quarter of 2016. Net loss for the first quarter of 2016 was $(8.6) million, or $(0.14) per unit, compared to net income of $36.5 million, or $0.58 per unit, for the same period last year.
Paul Eisman, President and CEO, commented, “Our first quarter results were negatively impacted by depressed crack spreads, narrow crude differentials and by planned downtime at our Big Spring refinery which included completing a reformer regeneration and a catalyst replacement for our diesel hydrotreater unit. The average benchmark crack spread was approximately $6.50 per barrel lower than the average in the first quarter 2015. It is not unusual for us to experience margin weakness in the first quarter, and we are encouraged by improvements in the benchmark crack spreads going into the second quarter. Demand for gasoline is strong and distillate demand is improving. We’ve also seen some improvement in the Midland differentials which should support improved refinery profitability.
“The Big Spring refinery achieved a refinery operating margin of $7.77 per barrel and direct operating expense of $4.07 per barrel in the first quarter. We expect total throughput at the Big Spring refinery to average approximately 74,000 barrels per day for the second quarter and 73,000 barrels per day for the full year of 2016.
“Market conditions and the planned downtime to complete a reformer regeneration and a catalyst replacement for our diesel hydrotreater unit during the first quarter did not allow us to generate sufficient cash to support a distribution. However, based on current forward curve crack spreads, it is our expectation that with operations consistent with our plan we should generate sufficient cash available for distribution during the second quarter.”
FIRST QUARTER 2016
Refinery operating margin was $7.77 per barrel for the first quarter of 2016 compared to $13.80 per barrel for the same period in 2015. This decrease in operating margin was primarily due to a lower Gulf Coast 3/2/1 crack spread and a narrowing of both the WTI Cushing to WTI Midland and the WTI Cushing to WTS spreads, partially offset by the cost of crude benefit from the market moving further into contango in 2016. The Big Spring refinery average throughput for the first quarter of 2016 was 67,536 barrels per day (“bpd”) compared to 72,360 bpd for the same period in 2015. The reduced throughput at our refinery was the result of planned downtime to complete a reformer regeneration and catalyst replacement for our diesel hydrotreater unit in the beginning of the first quarter of 2016.
The average Gulf Coast 3/2/1 crack spread was $11.24 per barrel for the first quarter of 2016 compared to $17.74 per barrel for the first quarter of 2015. The average WTI Cushing to WTI Midland spread for the first quarter of 2016 was $(0.13) per barrel compared to $1.95 per barrel for the first quarter of 2015. The average WTI Cushing to WTS spread for the first quarter of 2016 was $(0.10) per barrel compared to $1.76 per barrel for the first quarter of 2015. The average Brent to WTI Cushing spread for the first quarter of 2016 was $0.49 per barrel compared to $5.44 per barrel for the same period in 2015. The contango environment in the first quarter of 2016 created an average cost of crude benefit of $1.83 per barrel compared to an average cost of crude benefit of $0.65 per barrel for the same period in 2015.

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CONFERENCE CALL
Alon Partners has scheduled a conference call, which will be broadcast live over the Internet on Thursday, May 5, 2016 at 10:00 a.m. Eastern Time (9:00 a.m. Central Time), to discuss the first quarter 2016 financial results. To access the call, please dial 877-404-9648, or 412-902-0030 for international callers, and ask for the Alon Partners call at least 10 minutes prior to the start time. Investors may also 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 May 19, 2016, and may be accessed by calling 877-660-6853, or 201-612-7415 for international callers, and using the passcode 13634013#. A webcast archive 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.
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. Additional information regarding these and other risks is contained in our filings with the Securities and Exchange Commission.
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 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 both Alon Energy’s retail convenience stores and other third-party distributors.

- Tables to follow -

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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, 2015, IS UNAUDITED)
For the Three Months Ended
 
March 31,
 
2016
 
2015
 
(dollars in thousands, except per unit data, per barrel data and pricing statistics)
STATEMENTS OF OPERATIONS DATA:
 
 
 
Net sales (1)
$
368,009

 
$
542,442

Operating costs and expenses:
 
 
 
Cost of sales
319,333

 
450,595

Direct operating expenses
25,044

 
23,416

Selling, general and administrative expenses
7,309

 
5,903

Depreciation and amortization
14,206

 
13,993

Total operating costs and expenses
365,892

 
493,907

Operating income
2,117

 
48,535

Interest expense
(10,587
)
 
(11,693
)
Other income (loss), net
84

 
(41
)
Income (loss) before state income tax expense
(8,386
)
 
36,801

State income tax expense
176

 
350

Net income (loss)
$
(8,562
)
 
$
36,451

Earnings (loss) per unit
$
(0.14
)
 
$
0.58

Weighted average common units outstanding (in thousands)
62,510

 
62,507

Cash distribution per unit
$
0.08

 
$
0.70

CASH FLOW DATA:
 
 
 
Net cash provided by (used in):
 
 
 
Operating activities
$
6,662

 
$
27,087

Investing activities
(10,793
)
 
(3,805
)
Financing activities
(5,626
)
 
(19,220
)
OTHER DATA:
 
 
 
Adjusted EBITDA (2)
$
16,407

 
$
62,487

Capital expenditures
8,112

 
2,321

Capital expenditures for turnarounds and catalysts
2,681

 
1,484

KEY OPERATING STATISTICS:
 
 
 
Per barrel of throughput:
 
 
 
Refinery operating margin (3)
$
7.77

 
$
13.80

Refinery direct operating expense (4)
4.07

 
3.60

PRICING STATISTICS:
 
 
 
Crack spreads (per barrel):
 
 
 
Gulf Coast 3/2/1 (5)
$
11.24

 
$
17.74

WTI Cushing crude oil (per barrel)
$
33.30

 
$
48.48

Crude oil differentials (per barrel):
 
 
 
WTI Cushing less WTI Midland (6)
$
(0.13
)
 
$
1.95

WTI Cushing less WTS (6)
(0.10
)
 
1.76

Brent less WTI Cushing (6)
0.49

 
5.44

Product price (dollars per gallon):
 
 
 
Gulf Coast unleaded gasoline
$
1.07

 
$
1.52

Gulf Coast ultra-low sulfur diesel
1.03

 
1.69

Natural gas (per MMBtu)
1.98

 
2.81


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March 31,
2016
 
December 31,
2015
BALANCE SHEET DATA (end of period):
 (dollars in thousands)
Cash and cash equivalents
$
123,196

 
$
132,953

Working capital
(66,936
)
 
(53,804
)
Total assets
745,428

 
748,584

Total debt
291,868

 
292,082

Total debt less cash and cash equivalents
168,672

 
159,129

Total partners’ equity
117,404

 
130,957

THROUGHPUT AND PRODUCTION DATA:
For the Three Months Ended
March 31,
 
2016
 
2015
 
bpd
 
%
 
bpd
 
%
Refinery throughput:
 
 
 
 
 
 
 
WTS crude
36,554

 
54.1

 
44,865

 
62.0

WTI crude
27,760

 
41.1

 
24,137

 
33.4

Blendstocks
3,222

 
4.8

 
3,358

 
4.6

Total refinery throughput (7)
67,536

 
100.0

 
72,360

 
100.0

Refinery production:
 
 
 
 
 
 
 
Gasoline
34,100

 
50.5

 
36,192

 
49.7

Diesel/jet
22,682

 
33.6

 
26,086

 
35.9

Asphalt
3,148

 
4.6

 
3,278

 
4.5

Petrochemicals
3,617

 
5.3

 
4,810

 
6.6

Other
4,027

 
6.0

 
2,394

 
3.3

Total refinery production (8)
67,574

 
100.0

 
72,760

 
100.0

Refinery utilization (9)
 
 
93.2
%
 
 
 
94.5
%

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CASH AVAILABLE FOR DISTRIBUTION DATA:
 
For the Three Months Ended
 
 
March 31, 2016
 
 
(dollars in thousands, except per unit data)
 
 
 
Net sales (1)
 
$
368,009

Operating costs and expenses:
 
 
Cost of sales
 
319,333

Direct operating expenses
 
25,044

Selling, general and administrative expenses
 
7,309

Depreciation and amortization
 
14,206

Total operating costs and expenses
 
365,892

Operating income
 
2,117

Interest expense
 
(10,587
)
Other income, net
 
84

Loss before state income tax expense
 
(8,386
)
State income tax expense
 
176

Net loss
 
(8,562
)
Adjustments to reconcile net loss to Adjusted EBITDA:
 
 
Interest expense
 
10,587

State income tax expense
 
176

Depreciation and amortization
 
14,206

Adjusted EBITDA (2)
 
16,407

Adjustments to reconcile Adjusted EBITDA to cash available for distribution:
 
 
less: Maintenance/growth capital expenditures
 
8,112

less: Turnaround and catalyst replacement capital expenditures
 
2,681

less: Major turnaround reserve for future years
 
1,500

less: Principal payments
 
625

less: State income tax payments
 
176

less: Interest paid in cash
 
10,144

Calculated cash available for distribution
 
$
(6,831
)
Cash available for distribution
 
$
—

 
 
 
Common units outstanding (in 000’s)
 
62,510

 
 
 
Cash available for distribution per unit
 
$
—

________________
(1)
Includes sales to related parties of $63,110 and $82,889 for the three months ended March 31, 2016 and 2015, respectively.
(2)
Adjusted EBITDA represents earnings before state income tax expense, interest expense and depreciation and amortization. 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 and the accounting effects of capital expenditures and acquisitions, items that may vary for different companies for reasons unrelated to overall operating performance.

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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 (loss) to Adjusted EBITDA for the three months ended March 31, 2016 and 2015:
 
For the Three Months Ended
 
March 31,
 
2016
 
2015
 
(dollars in thousands)
Net income (loss)
$
(8,562
)
 
$
36,451

State income tax expense
176

 
350

Interest expense
10,587

 
11,693

Depreciation and amortization
14,206

 
13,993

Adjusted EBITDA
$
16,407

 
$
62,487

(3)
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 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.
Refinery operating margin for the three months ended March 31, 2016 and 2015 excludes gains related to inventory adjustments of $946 and $1,990, respectively.
(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 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.
(6)
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.
(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.

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