Alon USA Reports Second Quarter Results

Declares Quarterly Cash Dividend

Company schedules conference call for August 7, 2013 at 11:30 a.m. Eastern

Aug 06, 2013, 22:45 ET from Alon USA Energy, Inc.

DALLAS, Aug. 6, 2013 /PRNewswire/ -- Alon USA Energy, Inc. (NYSE: ALJ) ("Alon") today announced results for the second quarter of 2013. Net income for the second quarter of 2013 was $19.9 million of which $8.4 million was attributable to non-controlling interest, resulting in net income available to stockholders of $11.5 million, or $0.17 per share, compared to net income available to stockholders of $43.1 million, or $0.77 per share, for the same period last year. Excluding special items, Alon recorded net income available to stockholders of $17.2 million, or $0.27 per share, for the second quarter of 2013, compared to net income available to stockholders of $35.2 million, or $0.63 per share, for the same period last year.

Net income for the first half of 2013 was $93.6 million of which $27.9 million was attributable to non-controlling interest, resulting in net income available to stockholders of $65.7 million, or $1.03 per share, compared to net income available to stockholders of $13.7 million, or $0.24 per share, for the same period last year. Excluding special items, Alon recorded net income available to stockholders of $71.4 million, or $1.12 per share, for the first half of 2013, compared to net income available to stockholders of $43.7 million, or $0.78 per share, for the same period last year.

The following reconciles net income available to stockholders to net income.

For the Three Months Ended

For the Six Months Ended

June 30,

June 30,

2013

2012

2013

2012

(dollars in thousands)

Net income available to stockholders

$

11,496

$

43,091

$

65,680

$

13,724

Plus: Net income attributable to non-controlling interest

8,446

2,183

27,913

440

Net income

$

19,942

$

45,274

$

93,593

$

14,164

Paul Eisman, CEO and President, commented, "Our Big Spring refinery had an excellent operational quarter recording its highest ever quarterly crude throughput of 70,807 barrels per day with total throughput of 72,124 barrels per day. We experienced a sharp decline in the WTI to WTS spread, declining approximately $11 per barrel for the second quarter compared to first quarter of 2013. The Gulf Coast 3/2/1 crack spreads declined by approximately $7 per barrel for the second quarter compared to first quarter of 2013. We are focused on opportunities to improve our assets and are planning a project that will be implemented during the Big Spring turnaround in 2014 that will increase overall distillate yield by 2% and will also increase total refinery throughput by 3,000 barrels per day.

"At Krotz Springs, we were able to increase our utilization of WTI in the second quarter to 31,000 barrels per day from 25,000 barrels per day in the first quarter of this year. In the quarter we incurred one-time costs affecting our Krotz Springs refining margin and operating expense totaling approximately $17 million or $3.11 per barrel related to downtime and repairs to the reformer unit. The refinery was returned to normal operations in early June after the repairs and is operating well. We completed work on the railcar unloading terminal facility at the Krotz Springs refinery and began receiving WTI crude oil with our existing railcars in late June. Crude differentials narrowed in the second quarter of 2013 compared to the first quarter of 2013, increasing the cost of WTI priced crude barrels at the Krotz Springs refinery on average by $16 per barrel. We also saw industry average Gulf Coast 2/1/1 high sulfur diesel to LLS crack spreads decline by approximately $4 per barrel for the second quarter compared to first quarter of 2013.

"In the second quarter we were impacted by sharp increases in RINs prices as we recorded approximately $8 million of expense. We are actively working to mitigate these costs by increasing branded and unbranded sales throughout our system, and also by blending biodiesel into our Big Spring product beginning in September. Based on current RINs pricing, we estimate our total RINs obligations for the year will be approximately $20 million.

"In California, we continue to work on permitting of our rail terminal and refinery light crude modification project, and expect to receive the permits during the fourth quarter. In addition, we are continuing work to utilize our logistical assets on the West Coast to provide terminaling services to third parties.

"For the third quarter of 2013, we expect the throughput at both the Big Spring and Krotz Springs refineries to average approximately 69,000 barrels per day. At Krotz Springs, we are planning to process 30,000 barrels per day of WTI during the third quarter of 2013."

SECOND QUARTER 2013

Special items decreased earnings by $5.7 million for the second quarter of 2013 which primarily included after-tax costs for an unplanned reformer shutdown and repair of $11.6 million offset by $5.9 million associated with gains recognized on disposition of assets. Special items increased earnings by $7.9 million for the second quarter of 2012 which primarily included after-tax gains of $7.6 million associated with gains on commodity swaps, $0.5 million associated with heating oil call option crack spread contracts offset by $0.2 million associated with losses recognized on disposition of assets.

The combined refinery throughput for the second quarter of 2013 averaged 130,928 barrels per day ("bpd"), consisting of 72,124 bpd at the Big Spring refinery and 58,804 bpd at the Krotz Springs refinery, compared to 160,071 bpd for the second quarter of 2012, consisting of 64,558 bpd at the Big Spring refinery, 31,206 bpd at the California refineries and 64,307 bpd at the Krotz Springs refinery. The lower throughput rates were due to the California refineries being shut down during the first half of 2013 as well as the impact of the Krotz Springs refinery unplanned shut down and repair of the reformer unit for approximately one month.

Refinery operating margin at the Big Spring refinery was $16.21 per barrel for the second quarter of 2013 compared to $25.79 per barrel for the same period in 2012. This decrease is mainly due to lower Gulf Coast 3/2/1 crack spreads and a narrowing WTI to WTS spread. The Krotz Springs refinery operating margin was $2.30 per barrel for the second quarter of 2013 compared to $5.28 per barrel for the same period in 2012. This decrease is mainly due to costs incurred from the unplanned shut down of the reformer unit and lower Gulf Coast 2/1/1 crack spreads, partially offset by the higher utilization of lower cost WTI priced crude oils.

The average Gulf Coast 3/2/1 crack spread for the second quarter of 2013 was $21.17 per barrel compared to $26.04 per barrel for the same period in 2012. The average Gulf Coast 2/1/1 high sulfur diesel crack spread for the second quarter of 2013 was $4.15 per barrel compared to $7.72 per barrel for the same period in 2012.

The average WTI to WTS spread for the second quarter of 2013 was $0.36 per barrel compared to $5.36 per barrel for the same period in 2012. The average LLS to WTI spread for the second quarter of 2013 was $15.07 per barrel compared to $18.11 per barrel for the same period in 2012.

Asphalt margins for the second quarter of 2013 were $83.27 per ton compared to $67.31 per ton for the same period in 2012. On a cash basis (i.e. excluding inventory effects), asphalt margins in the second quarter of 2013 were $90.06 per ton compared to $43.34 per ton in the second quarter of 2012. This increase is primarily due to lower costs winter fill asphalt sold during the second quarter of 2013. The average blended asphalt sales price decreased 2.8% from $608.81 per ton in the second quarter of 2012 to $591.81 per ton in the second quarter of 2013 and the average non-blended asphalt sales price decreased 18.0% from $471.41 per ton in the second quarter of 2012 to $386.40 per ton in the second quarter of 2013.

Retail fuel sales volume increased by 14.5% from 41.5 million gallons in the second quarter of 2012 to 47.5 million gallons in the second quarter of 2013.

YEAR-TO-DATE 2013

Special items decreased earnings by $5.7 million for the first half of 2013 which primarily included after-tax costs for an unplanned reformer shutdown and repair of $11.6 million, offset by $6.0 million associated with gains recognized on disposition of assets. Special items decreased earnings by $30.0 million for the first half of 2012 which primarily included after-tax losses of $19.6 million associated with losses on commodity swaps, $4.4 million associated with heating oil call option crack spread contracts, $5.8 million associated with the write-off of unamortized original issuance discount due to a term loan repayment and $0.2 million associated with losses recognized on disposition of assets.

The combined refinery throughput for the first half of 2013 averaged 124,457 bpd, consisting of 65,835 bpd at the Big Spring refinery and 58,622 bpd at the Krotz Springs refinery, compared to 148,027 bpd for the first half of 2012, consisting of 67,035 bpd at the Big Spring refinery, 16,000 bpd at the California refineries and 64,992 bpd at the Krotz Springs refinery. The lower throughput rates were due to the California refineries being shut down during the first half of 2013 as well as the impact of the Krotz Springs refinery unplanned shut down and repair of the reformer unit for approximately one month.

Refinery operating margin at the Big Spring refinery was $21.85 per barrel for the first half of 2013 compared to $20.32 per barrel for the same period in 2012. This increase is mainly due to a wider WTI to WTS spread, partially offset by lower Gulf Coast 3/2/1 crack spreads. The Krotz Springs refinery operating margin was $7.67 per barrel for the first half of 2013 compared to $5.55 per barrel for the same period in 2012. This increase is mainly due to the higher utilization of lower cost WTI priced crude oils, partially offset by lower Gulf Coast 2/1/1 crack spreads.

The average Gulf Coast 3/2/1 crack spread for the first half of 2013 was $24.76 per barrel compared to $25.41 per barrel for the same period in 2012. The average Gulf Coast 2/1/1 high sulfur diesel crack spread for the first half of 2013 was $6.16 per barrel compared to $10.09 per barrel for the same period in 2012.

The average WTI to WTS spread for the first half of 2013 was $5.86 per barrel compared to $3.76 per barrel for the same period in 2012. The average LLS to WTI spread for the first half of 2013 was $17.63 per barrel compared to $15.36 per barrel for the same period in 2012.

Asphalt margins for the first half of 2013 were $73.74 per ton compared to $62.30 per ton for same period in 2012. On a cash basis (i.e. excluding inventory effects), asphalt margins in the first half of 2013 were $77.81 per ton compared to $26.71 per ton in the first half of 2012. This increase is primarily due to lower costs winter fill asphalt sold during the first half of 2013. The average blended asphalt sales price decreased 4.3% from $595.62 per ton in the first half of 2012 to $570.28 per ton in the first half of 2013 and the average non-blended asphalt sales price increased 3.0% from $378.30 per ton in the first half of 2012 to $389.59 per ton in the first half of 2013.

Retail fuel sales volume increased by 10.9% from 82.9 million gallons in the first half of 2012 to 91.9 million gallons in the first half of 2013.

Alon also announced today that its Board of Directors has approved the regular quarterly cash dividend of $0.06 per share. The dividend is payable on September 19, 2013 to stockholders of record at the close of business on September 5, 2013.

CONFERENCE CALL

The Company has scheduled a conference call for Wednesday, August 7, 2013, at 11:30 a.m. Eastern, to discuss the second quarter 2013 results. To access the call, please dial 800-762-8779, or 480-629-9819, for international callers, at least 10 minutes prior to the start time and ask for the Alon USA Energy call. Investors may also access the live webcast on the Alon corporate website, http://www.alonusa.com, by logging onto that site and clicking "Investors". A telephonic replay of the conference call will be available through August 21, 2013, and may be accessed by calling 800-406-7325, or 303-590-3030, for international callers, and using the passcode 4630324#. The archived webcast will also be available at http://www.alonusa.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.

Alon USA Energy, Inc., headquartered in Dallas, Texas, is an independent refiner and marketer of petroleum products, operating primarily in the South Central, Southwestern and Western regions of the United States. The Company directly owns crude oil refineries in California, Louisiana and Oregon, with an aggregate crude oil throughput capacity of approximately 144,000 barrels per day. Alon USA also owns 100% of the general partner and approximately 82% of the limited partner interests in Alon USA Partners, LP (NYSE: ALDW), which owns a crude oil refinery in Texas with an aggregate crude oil throughput capacity of approximately 70,000 barrels per day. Alon USA is a leading producer of asphalt, which it markets through its asphalt terminals predominately in the Western United States. Alon USA is the largest 7-Eleven licensee in the United States and operates approximately 300 convenience stores in Texas and New Mexico.

Any statements in this press 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.

This press release does not constitute an offer to sell or the solicitation of offers to buy any security and shall not constitute an offer, solicitation or sale of any security in any jurisdiction in which such offer, solicitation or sale would be unlawful.

 

Contacts:

Claire Hart, Senior Vice President

Alon USA Energy, Inc.

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 ENERGY, INC. 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

For the Six Months Ended

June 30,

June 30,

2013

2012

2013

2012

(dollars in thousands, except per share data)

STATEMENTS OF OPERATIONS DATA:

Net sales (1)

$

1,676,595

$

1,910,489

$

3,327,791

$

3,702,622

Operating costs and expenses:

Cost of sales

1,497,712

1,686,876

2,875,969

3,305,550

Unrealized (gains) losses on commodity swaps

(12,871)

32,441

Direct operating expenses

71,446

76,874

145,668

149,083

Selling, general and administrative expenses (2)

43,101

36,208

84,842

71,348

Depreciation and amortization (3)

30,798

30,419

61,961

61,130

   Total operating costs and expenses

1,643,057

1,817,506

3,168,440

3,619,552

Gain (loss) on disposition of assets

8,494

(345)

8,512

(214)

Operating income

42,032

92,638

167,863

82,856

Interest expense (4)

(20,261)

(24,300)

(41,553)

(55,340)

Equity earnings of investees

2,110

1,509

1,729

1,570

Other income (loss), net (5)

46

1,107

129

(6,993)

Income before income tax expense

23,927

70,954

128,168

22,093

Income tax expense

3,985

25,680

34,575

7,929

Net income

19,942

45,274

93,593

14,164

Net income attributable to non-controlling interest

8,446

2,183

27,913

440

Net income available to stockholders

$

11,496

$

43,091

$

65,680

$

13,724

Earnings per share, basic

$

0.17

$

0.77

$

1.03

$

0.24

Weighted average shares outstanding, basic (in thousands)

62,614

56,238

62,285

56,133

Earnings per share, diluted

$

0.17

$

0.65

$

0.97

$

0.21

Weighted average shares outstanding, diluted (in thousands)

68,071

66,635

67,743

66,562

Cash dividends per share

$

0.22

$

0.04

$

0.26

$

0.08

CASH FLOW DATA:

Net cash provided by (used in):

Operating activities

$

(31,016)

$

83,349

$

129,754

$

114,222

Investing activities

1,491

(32,615)

(12,082)

(49,266)

Financing activities

(88,873)

(43,507)

(99,500)

(164,506)

OTHER DATA:

Adjusted net income available to stockholders (6)

$

17,200

$

35,219

$

71,372

$

43,668

Adjusted earnings per share (6)

$

0.27

$

0.63

$

1.12

$

0.78

Adjusted EBITDA (7)

$

66,492

$

112,291

$

223,170

$

178,515

Capital expenditures (8)

22,208

25,968

30,622

40,525

Capital expenditures for turnaround and chemical catalyst

1,408

6,652

6,624

8,757

 

 

June 30,

2013

December 31,

2012

BALANCE SHEET DATA (end of period):

(dollars in thousands)

Cash and cash equivalents

$

134,468

$

116,296

Working capital

173,604

87,242

Total assets

2,246,665

2,223,574

Total debt

529,764

587,017

Total debt less cash and cash equivalents

395,296

470,721

Total equity

684,452

621,186

 

 

REFINING AND MARKETING SEGMENT (A)

For the Three Months Ended

For the Six Months Ended

June 30,

June 30,

2013

2012

2013

2012

(dollars in thousands, except per barrel data and pricing statistics)

STATEMENTS OF OPERATIONS DATA:

Net sales (9)

$

1,443,614

$

1,753,843

$

2,857,739

$

3,389,651

Operating costs and expenses:

Cost of sales

1,316,953

1,584,004

2,500,275

3,087,397

Unrealized (gains) losses on commodity swaps

(12,871)

32,441

Direct operating expenses

60,347

68,523

124,016

131,742

Selling, general and administrative expenses

14,598

9,073

28,519

17,609

Depreciation and amortization

26,107

25,758

52,612

52,035

   Total operating costs and expenses

1,418,005

1,674,487

2,705,422

3,321,224

Gain on disposition of assets

7,405

4

7,405

4

Operating income

$

33,014

$

79,360

$

159,722

$

68,431

KEY OPERATING STATISTICS:

Per barrel of throughput:

Refinery operating margin – Big Spring (10)

$

16.21

$

25.79

$

21.85

$

20.32

Refinery operating margin – CA Refineries (10)

N/A

2.55

N/A

3.11

Refinery operating margin – Krotz Springs (10)

2.30

5.28

7.67

5.55

Refinery direct operating expense – Big Spring (11)

4.16

4.27

4.85

3.92

Refinery direct operating expense – CA Refineries (11)

N/A

7.41

N/A

12.96

Refinery direct operating expense – Krotz Springs (11)

4.63

3.83

4.53

3.91

Capital expenditures

$

12,646

$

17,476

$

18,615

$

26,177

Capital expenditures for turnaround and chemical catalyst

1,408

6,652

6,624

8,757

PRICING STATISTICS:

Crack spreads (3/2/1) (per barrel):

Gulf Coast (12)

$

21.17

$

26.04

$

24.76

$

25.41

Crack spreads (3/1/1/1) (per barrel):

West Coast (12)

$

9.78

$

11.46

$

10.42

$

12.05

Crack spreads (2/1/1) (per barrel):

Gulf Coast high sulfur diesel (12)

$

4.15

$

7.72

$

6.16

$

10.09

WTI crude oil (per barrel)

94.20

93.45

94.23

98.23

Crude oil differentials (per barrel):

WTI less WTS (13)

$

0.36

$

5.36

$

5.86

$

3.76

LLS less WTI (13)

15.07

18.11

17.63

15.36

WTI less Buena Vista (13)

(10.50)

(14.80)

(13.12)

(13.89)

Product prices (dollars per gallon):

Gulf Coast unleaded gasoline

$

2.69

$

2.80

$

2.77

$

2.89

Gulf Coast ultra-low sulfur diesel

2.86

2.95

2.97

3.05

Gulf Coast high sulfur diesel

2.71

2.89

2.86

3.00

West Coast LA CARBOB (unleaded gasoline)

2.99

3.03

3.04

3.11

West Coast LA ultra-low sulfur diesel

2.89

2.97

3.01

3.11

Natural gas (per MMBtu)

4.02

2.35

3.76

2.43

(A)

In the fourth quarter of 2012, based on a change in our internal reporting structure as a result of the Alon USA Partners, LP initial public offering, the branded marketing operations have been combined with the refining and marketing segment and are no longer included with the retail segment. Information for the three and six months ended June 30, 2012 has been recast to provide a comparison to the current period results.

 

 

THROUGHPUT AND PRODUCTION DATA:

BIG SPRING REFINERY

For the Three Months Ended

For the Six Months Ended

June 30,

June 30,

2013

2012

2013

2012

bpd

%

bpd

%

bpd

%

bpd

%

Refinery throughput:

WTS crude

53,627

74.4

52,250

81.0

49,446

75.1

53,898

80.4

WTI crude

17,180

23.8

10,738

16.6

14,380

21.8

11,472

17.1

Blendstocks

1,317

1.8

1,570

2.4

2,009

3.1

1,665

2.5

Total refinery throughput (14)

72,124

100.0

64,558

100.0

65,835

100.0

67,035

100.0

Refinery production:

Gasoline

35,057

48.7

30,885

47.8

32,436

49.4

33,012

49.2

Diesel/jet

24,748

34.4

21,242

32.9

22,038

33.6

21,739

32.5

Asphalt

4,453

6.2

4,041

6.2

3,909

6.0

4,288

6.4

Petrochemicals

4,628

6.4

3,838

5.9

4,179

6.4

3,988

6.0

Other

3,088

4.3

4,655

7.2

3,029

4.6

3,921

5.9

Total refinery production (15)

71,974

100.0

64,661

100.0

65,591

100.0

66,948

100.0

Refinery utilization (16)

101.2

%

98.9

%

97.1

%

97.8

%

THROUGHPUT AND PRODUCTION DATA:

CALIFORNIA REFINERIES

For the Three Months Ended

For the Six Months Ended

June 30,

June 30,

2013

2012

2013

2012

bpd

%

bpd

%

bpd

%

bpd

%

Refinery throughput:

Medium sour crude

4,910

15.7

3,167

19.8

Heavy crude

23,367

74.9

11,368

71.0

Blendstocks

2,929

9.4

1,465

9.2

Total refinery throughput (14)

31,206

100.0

16,000

100.0

Refinery production:

Gasoline

3,406

11.0

1,700

10.7

Diesel/jet

7,328

23.7

3,663

23.1

Asphalt

9,920

32.1

5,086

32.1

Light unfinished

684

2.2

506

3.2

Heavy unfinished

8,983

29.1

4,596

29.0

Other

599

1.9

300

1.9

Total refinery production (15)

30,920

100.0

15,851

100.0

Refinery utilization (16)

%

39.0

%

%

20.0

%

THROUGHPUT AND PRODUCTION DATA:

KROTZ SPRINGS REFINERY

For the Three Months Ended

For the Six Months Ended

June 30,

June 30,

2013

2012

2013

2012

bpd

%

bpd

%

bpd

%

bpd

%

Refinery throughput:

WTI crude

31,060

52.8

17,378

27.0

28,088

47.9

13,344

20.5

Gulf Coast sweet crude

26,226

44.6

46,905

73.0

28,857

49.2

51,128

78.7

Blendstocks

1,518

2.6

24

1,677

2.9

520

0.8

Total refinery throughput (14)

58,804

100.0

64,307

100.0

58,622

100.0

64,992

100.0

Refinery production:

Gasoline

22,710

37.9

26,486

40.6

24,800

41.5

26,400

40.3

Diesel/jet

24,267

40.5

27,270

41.9

23,330

39.0

27,991

42.8

Heavy Oils

521

0.9

2,511

3.9

1,144

1.9

2,830

4.3

Other

12,410

20.7

8,822

13.6

10,559

17.6

8,223

12.6

Total refinery production (15)

59,908

100.0

65,089

100.0

59,833

100.0

65,444

100.0

Refinery utilization (16)

68.9

%

77.4

%

71.5

%

77.6

%

 

 

ASPHALT SEGMENT

For the Three Months Ended

For the Six Months Ended

June 30,

June 30,

2013

2012

2013

2012

(dollars in thousands, except per ton data)

STATEMENTS OF OPERATIONS DATA:

Net sales (17)

$

144,191

$

152,911

$

299,056

$

245,460

Operating costs and expenses:

Cost of sales (17)(18)

127,953

135,748

273,469

218,420

Direct operating expenses

11,099

8,351

21,652

17,341

Selling, general and administrative expenses

1,555

994

3,203

1,920

Depreciation and amortization

1,563

1,414

3,112

2,796

   Total operating costs and expenses

142,170

146,507

301,436

240,477

Operating income (loss)

$

2,021

$

6,404

$

(2,380)

$

4,983

KEY OPERATING STATISTICS:

Blended asphalt sales volume (tons in thousands) (19)

180

238

310

374

Non-blended asphalt sales volume (tons in thousands) (20)

15

17

37

60

Blended asphalt sales price per ton (19)

$

591.81

$

608.81

$

570.28

$

595.62

Non-blended asphalt sales price per ton (20)

386.40

471.41

389.59

378.30

Asphalt margin per ton (21)

83.27

67.31

73.74

62.30

Capital expenditures

$

2,599

$

5,969

$

4,391

$

7,460

RETAIL SEGMENT (A)

For the Three Months Ended

For the Six Months Ended

June 30,

June 30,

2013

2012

2013

2012

(dollars in thousands, except per gallon data)

STATEMENTS OF OPERATIONS DATA:

Net sales (1)

$

244,833

 

$

232,239

$

468,938

$

448,881

Operating costs and expenses:

Cost of sales (18)

208,849

195,628

400,167

381,103

Selling, general and administrative expenses

26,755

25,950

52,752

51,438

Depreciation and amortization

2,554

2,623

4,822

5,122

   Total operating costs and expenses

238,158

224,201

457,741

437,663

Gain (loss) on disposition of assets

1,089

(349)

1,107

(218)

Operating income

$

7,764

 

$

7,689

$

12,304

$

11,000

KEY OPERATING STATISTICS:

Number of stores (end of period) (22)

298

300

298

300

Retail fuel sales (thousands of gallons)

47,490

41,538

91,896

82,867

Retail fuel sales (thousands of gallons per site per month) (22)

55

48

54

48

Retail fuel margin (cents per gallon) (23)

20.2

22.5

20.2

20.2

Retail fuel sales price (dollars per gallon) (24)

$

3.40

 

$

3.60

$

3.40

$

3.53

Merchandise sales

$

83,243

 

$

82,511

$

156,576

$

155,993

Merchandise sales (per site per month) (22)

$

93

$

92

$

88

$

87

Merchandise margin (25)

31.6

%

32.9

%

31.9

%

32.6

%

Capital expenditures

$

6,537

 

$

1,866

$

7,177

$

6,105

(A)

In the fourth quarter of 2012, based on a change in our internal reporting structure as a result of the Alon USA Partners, LP initial public offering, the branded marketing operations have been combined with the refining and marketing segment and are no longer included with the retail segment. Information for the three and six months ended June 30, 2012 has been recast to provide a comparison to the current period results.

 

 

(1)

Includes excise taxes on sales by the retail segment of $18,531 and $16,198 for the three months ended June 30, 2013 and 2012, respectively, and $35,836 and $32,322 for the six months ended June 30, 2013 and 2012, respectively.

(2)

Includes corporate headquarters selling, general and administrative expenses of $193 and $191 for the three months ended June 30, 2013 and 2012, respectively, and $368 and $381 for the six months ended June 30, 2013 and 2012, respectively, which are not allocated to our three operating segments.

(3)

Includes corporate depreciation and amortization of $574 and $624 for the three months ended June 30, 2013 and 2012, respectively, and $1,415 and $1,177 for the six months ended June 30, 2013 and 2012, respectively, which are not allocated to our three operating segments.

(4)

Interest expense for the six months ended June 30, 2012, includes a charge of $9,624 for the write-off of unamortized original issuance discount associated with a term loan repayment.

(5)

Other income (loss), net for both the three and six months ended June 30, 2012, is substantially the gain (loss) on heating oil call option crack spread contracts.

(6)

The following table provides a reconciliation of net income available to stockholders under United States generally accepted accounting principles ("GAAP") to adjusted net income available to stockholders utilized in determining adjusted earnings per share, excluding the after-tax loss on write-off of unamortized original issuance discount, after-tax gain (loss) on heating oil call option crack spread contracts, after-tax unrealized gains (losses) on commodity swaps, after-tax costs associated with the unplanned reformer shutdown and repair and after-tax gain (loss) on disposition of assets. Our management believes that the presentation of adjusted net income available to stockholders and adjusted earnings per share, excluding these items, is useful to investors because it provides a more meaningful measurement for evaluation of our Company's operating results.

For the Three Months Ended

For the Six Months Ended

June 30,

June 30,

2013

2012

2013

2012

(dollars in thousands)

Net income available to stockholders

$

11,496

$

43,091

$

65,680

$

13,724

Plus: Write-off of original issuance discount, net of tax

5,781

Plus: (Gain) loss on heating oil call option crack spread contracts, net of tax

(484)

4,413

Plus: Unrealized (gains) losses on commodity swaps, net of tax

(7,596)

19,621

Plus: Costs associated with the unplanned reformer shutdown and repair

11,643

11,643

Less: (Gain) loss on disposition of assets, net of tax

(5,939)

208

(5,951)

129

Adjusted net income available to stockholders

$

17,200

$

35,219

$

71,372

$

43,668

Adjusted earnings per share *

$

0.27

$

0.63

$

1.12

$

0.78

* Adjusted earnings per share includes the effects of dividends on preferred stock on adjusted net income available to stockholders necessary to calculate earnings per share.

(7)

Adjusted EBITDA represents earnings before net income attributable to non-controlling interest, income tax expense, interest expense, depreciation and amortization, gain (loss) on disposition of assets, unrealized gains (losses) on commodity swaps and gain (loss) on heating oil call option crack spread contracts. 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 net income attributable to non-controlling interest, income tax expense, interest expense, gain (loss) on disposition of assets, unrealized gains (losses) on commodity swaps, gain (loss) on heating oil call option crack spread contracts 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 the prior claim that non-controlling interest have on the income generated by non-wholly-owned subsidiaries;
  • Adjusted EBITDA does not reflect changes in or cash requirements for our working capital needs; and
  • Our calculation of Adjusted EBITDA may differ from 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 available to stockholders to Adjusted EBITDA for the three and six months ended June 30, 2013 and 2012:

 

For the Three Months Ended

For the Six Months Ended

June 30,

June 30,

2013

2012

2013

2012

(dollars in thousands)

Net income available to stockholders

$

11,496

$

43,091

$

65,680

$

13,724

Net income attributable to non-controlling interest

8,446

2,183

27,913

440

Income tax expense

3,985

25,680

34,575

7,929

Interest expense

20,261

24,300

41,553

55,340

Depreciation and amortization

30,798

30,419

61,961

61,130

(Gain) loss on disposition of assets

(8,494)

345

(8,512)

214

Unrealized (gains) losses on commodity swaps

(12,871)

32,441

(Gain) loss on heating oil call option crack spread contracts

(856)

7,297

Adjusted EBITDA

$

66,492

$

112,291

$

223,170

$

178,515

(8)

Includes corporate capital expenditures of $426 and $657 for the three months ended June 30, 2013 and 2012, respectively, and $439 and $783 for the six months ended June 30, 2013 and 2012, respectively, which are not allocated to our three operating segments.

(9)

Net sales include intersegment sales to our asphalt and retail segments at prices which approximate wholesale market prices. These intersegment sales are eliminated through consolidation of our financial statements.

(10)

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) attributable to each refinery 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 margins to these crack spreads to assess our operating performance relative to other participants in our industry.

 

The refinery operating margin for the three and six months ended June 30, 2013 includes $3,830 and $6,794 of negative inventory effects. The refinery operating margin for the three and six months ended June 30, 2012 includes $648 and $337 of positive inventory effects.

 

The refinery operating margin excludes realized gains on commodity swaps of $10,018 and $9,994 for the three and six months ended June 30, 2013, as well as charges of $9,318 related to environmental compliance obligations for the three and six months ended June 30, 2013.

 

The refinery operating margin excludes realized losses on commodity swaps of $20,087 and $34,421 for the three and six months ended June 30, 2012.

(11)

Refinery direct operating expense is a per barrel measurement calculated by dividing direct operating expenses at our Big Spring, California and Krotz Springs refineries by the applicable refinery's total throughput volumes.

(12)

We compare our Big Spring refinery's 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 crude oil are converted, or cracked, into two barrels of Gulf Coast conventional gasoline and one barrel of Gulf Coast ultra-low sulfur diesel.

 

We compare our California refineries' operating margin to the West Coast 3/1/1/1 crack spread. A West Coast 3/1/1/1 crack spread is calculated assuming that three barrels of Buena Vista crude oil are converted into one barrel of West Coast LA CARBOB pipeline gasoline, one barrel of LA ultra-low sulfur pipeline diesel and one barrel of LA 380 pipeline CST fuel oil.

 

We compare our Krotz Springs refinery's operating margin to the Gulf Coast 2/1/1 crack spread. A Gulf Coast 2/1/1 crack spread is calculated assuming that two barrels of LLS crude oil are converted into one barrel of Gulf Coast conventional gasoline and one barrel of Gulf Coast high sulfur diesel.

(13)

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. The WTI less Buena Vista spread represents the differential between the average value per barrel of WTI crude oil and the average value per barrel of Buena Vista crude oil. The LLS less WTI spread represents the differential between the average value per barrel of LLS crude oil and the average value per barrel of WTI crude oil.

(14)

Total refinery throughput represents the total barrels per day of crude oil and blendstock inputs in the refinery production process. The California refineries suspended operations in December 2012 and therefore, no throughput data has been presented for the three and six months ended June 30, 2013. Throughput data for the California refineries for the six months ended June 30, 2012 reflects substantially three months of operations as the California refineries were not in operation for the first quarter of 2012.

(15)

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

(16)

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

(17)

Net sales and cost of sales for the three months and six months ended June 30, 2013 includes approximately $32,000 and $108,000 of asphalt purchases sold as part of a supply and offtake arrangement. The volumes associated with these sales are excluded from the Key Operating Statistics.

(18)

Cost of sales includes intersegment purchases of asphalt blends and motor fuels from our refining and marketing segment at prices which approximate wholesale market prices. These intersegment purchases are eliminated through consolidation of our financial statements.

(19)

Blended asphalt represents base asphalt that has been blended with other materials necessary to sell the asphalt as a finished product.

(20)

Non-blended asphalt represents base material asphalt and other components that require additional blending before being sold as a finished product.

(21)

Asphalt margin is a per ton measurement calculated by dividing the margin between net sales and cost of sales by the total sales volume. Asphalt margins are used in the asphalt industry to measure operating results related to asphalt sales.

(22)

At June 30, 2013 we had 298 retail convenience stores of which 286 sold fuel. At June 30, 2012 we had 300 retail convenience stores of which 287 sold fuel.

(23)

Retail fuel margin represents the difference between retail fuel sales revenue and the net cost of purchased retail fuel, including transportation costs and associated motor fuel taxes, expressed on a cents-per-gallon basis. Retail fuel margins are frequently used in the retail industry to measure operating results related to retail fuel sales.

(24)

Retail fuel sales price per gallon represents the average sales price for retail fuels sold through our retail convenience stores.

(25)

Merchandise margin represents the difference between merchandise sales revenues and the delivered cost of merchandise purchases, net of rebates and commissions, expressed as a percentage of merchandise sales revenues. Merchandise margins, also referred to as in-store margins, are commonly used in the retail industry to measure in-store, or non-fuel, operating results.

SOURCE Alon USA Energy, Inc.



RELATED LINKS

http://www.alonusa.com