Synergy Resources Reports Fourth Quarter and Year End 2016 Financial and Operating Results; Announces Company Name, Address and Ticker Symbol Change

DENVER, CO–(Marketwired – February 23, 2017) – Synergy Resources Corporation (NYSE MKT: SYRG) (“Synergy”, the “Company”, “we”, “us” or “our”), a U.S. oil and gas exploration and production company focused on the Wattenberg Area of the Denver-Julesburg Basin, reports its fourth quarter and year-end financial and operating results for the period ended December 31, 2016, and announces a company name, address and ticker symbol change.

Fourth Quarter and Year End 2016 Highlights

  • Revenues were $38.7 million and $107.1 million for the three and twelve months ended December 31, 2016, respectively
  • Net income was $5.3 million or $0.03 per diluted share and net loss was $219.2 million or $1.26 per diluted share for the three and twelve months ended December 31, 2016, respectively
  • Adjusted EBITDA was $25.5 million and $65.2 million for the three and twelve months ended December 31, 2016, respectively (see further discussion regarding the presentation of adjusted EBITDA in “About Non-GAAP Financial Measures” below)

Fourth Quarter and Year End 2016 Financial Results

The following tables present certain per unit metrics that compare results of the corresponding quarterly reporting periods:

                 
    Three Months Ended       Year Ended    
Net Volumes   12/31/2016   12/31/2015   % Chg.   12/31/2016   12/31/2015   % Chg.
Crude Oil (MBbls)   705   552   28%   2,257   2,073   9%
Natural Gas (MMcf)   3,095   2,659   16%   12,086   8,472   43%
Sales Volumes: (MBOE)   1,221   995   23%   4,271   3,485   23%
Average Daily Volumes                        
Daily Production (BOE/day)   13,269   10,815   23%   11,670   9,548   22%
Product Price Received                        
Crude Oil ($/Bbl)   $40.94   $34.37   19%   $34.43   $40.08   (14)%
Natural Gas ($/Mcf)   $3.18   $2.44   30%   $2.44   $2.71   (10)%
Average Realized Price ($/BOE)   $31.70   $25.58   24%   $25.09   $30.43   (18)%
Per unit cost information                        
Lease Operating Expense ($/BOE)   4.08   3.16   29%   4.67   4.61   1%
Production Tax ($/BOE)   2.64   1.92   38%   1.34   2.70   (50)%
DD&A Expense ($/BOE)   11.20   13.91   (19)%   10.93   17.81   (39)%
Non-Cash G&A Expense ($/BOE)   1.81   7.59   (76)%   2.22   4.23   (48)%
Cash G&A Expense ($/BOE)   4.21   7.92   (47)%   4.93   4.72   4%
Total G&A Expense ($/BOE)   6.02   15.51   (61)%   7.15   8.95   (20)%
                         

The volatility of oil and natural gas prices impacted the Company’s financial results throughout the year. The Company’s fourth quarter benefited from higher prices relative to the same period a year ago as realized oil prices increased approximately 19%, averaging $40.94 per barrel versus $34.37 in the fourth quarter of 2015. Natural gas prices averaged $3.18 per Mcf in the fourth quarter of 2016 compared to $2.44 a year ago, a 30% increase. For the full year, however, realized oil prices averaged $34.43, 14% lower than the full year 2015, while natural gas prices averaged $2.44 per Mcf, 10% lower than 2015.

Revenues for the three months ended December 31, 2016 increased 52% as compared to the three months ended December 31, 2015. This was due to the higher commodity prices realized in the quarter versus the comparable period a year ago, along with a 23% increase in sales volumes period over period. For the twelve months ending December 31, 2016, despite a 23% increase in sales volumes year over year, revenues increased only 1% as the lower prices received for the year offset the production growth.

Production taxes for the twelve months ended December 31, 2016 were favorably impacted by an adjustment of the Company’s assumed ad valorem tax rate based on its most recent filing and areas of activity. G&A expense for the twelve months ended December 31, 2016 as compared to the twelve months ended December 31, 2015 declined by approximately $647 thousand and on a per unit of production basis by 20% year over year.

Net income for the three months ended December 31, 2016 totaled $5.3 million, or $0.03 per diluted share, as compared to a net loss of $48.2 million, or $0.44 per share, in the three months ended December 31, 2015. For the twelve months ended December 31, 2016 the Company reported a net loss of $219.2 million, or $1.26 per share, as compared to a net loss of $131.7 million, or $1.27 per share in the prior year. Net losses reported in both years 2016 and 2015 were primarily the result of ceiling test writedowns of $215 million and $141 million, respectively, related to commodity price weakness over those periods.

Adjusted EBITDA for the three and twelve months ended December 31, 2016 was $25.5 million and $65.2 million, respectively, compared to $10.8 million and $86.7 million for the same three- and twelve-month periods in 2015, respectively.

2016 Operating Activity

 
2016 Operating Activity
    # of Wells Drilled   # of Wells Completed & Turned to Sales
    (Gross)   (Net)   (Gross)   (Net)
Vista Pad   7   6   10   9
Fagerberg Pad   14   13   14   13
Evans Pad   22   21        
Williams Pad   7   7        
Kawata Pad   6   4        
Total wells   56   51   24   22
                 
2016 Gross Lateral Footage
Drilled ~ 450,000            
Completed ~ 146,000            
Wells in Progress at YE ’16 ~ 410,000            
                 
 
Fagerberg Pad
    Average Daily Production (Gross) *
Zone Well Count   Oil (Bls)   Gas (Mcf)   BOE /d (2-stream)
Niobrara 10   376   779   506
Codell 4   388   680   501
* First 90 days of production
 

Management Commentary

Lynn A. Peterson, Chairman and CEO of Synergy commented, “The Synergy team delivered outstanding performance during 2016. While some of the many changes in 2016 are less tangible, such as moving to a calendar year end and the strengthened independence of our Board of Directors, other changes, highlighted by our acquisition of the Greeley Crescent acreage and the development of infrastructure, are features of 2016 that we are reminded of every day. Our staff nearly doubled in 2016 providing the capacity to create and begin executing on a development plan that has set the stage for differentiated growth over the coming quarters and years. All of this and much more was accomplished while simultaneously maintaining a strong financial position along with the operational flexibility to react to changing commodity prices.”

Mr. Peterson also noted that, “As we continue to gain confidence in commodity prices, our plan is to maintain a two rig drilling program during 2017. As a result, we now believe that capital expenditures and production for 2017 should be at the top end of our guidance range issued in September 2016. We intend to provide updated 2017 guidance as we exit the first quarter of 2017 and observe the initial performance from some of the Evans wells. We are drilling out plugs in the second tranche of six Evans wells, and the wells have been turned to flowback as that process is completed. Stimulation activity is now focused on the next group of five Evans wells on the eastern pad.”

Company Name, Address and Ticker Symbol Change

The Company intends to propose that its shareholders approve a change in its legal name to “SRC Energy Inc.” at its 2017 annual meeting. Pending the shareholder vote on the proposal, the Company intends to use the new name on a “doing business as” basis beginning on or about March 6, 2017. In addition, the Company’s domain name will become SRCenergy.com. On or about March 6, 2017 the company’s NYSE MKT ticker symbol will change to SRCI.

Synergy will be relocating to its new offices effective February 27th, 2017. Our phone numbers will not be impacted by this change.

SRC Energy Inc.
1675 Broadway, Suite 2600
Denver, CO 80202

Conference Call

The Company will host a conference call on Friday, February 24, 2017 at 11:00 a.m. Eastern time (9:00 a.m. Mountain time) to discuss the results. The call will be conducted by Chairman and CEO Lynn A. Peterson, CFO James Henderson, COOs Nick Spence and Mike Eberhard, and Manager of IR John Richardson. A Q&A session will immediately follow the discussion of the results for the quarter. Please refer to Synergy’s website at www.syrginfo.com for the current corporate presentation and other news and information.

Dial-in (Toll-Free): (877) 407-9122

Dial-in (International): (201) 493-6747

Replay Information:

The Company’s earnings call will be available via Webcast. A link to the Webcast can be found at www.syrginfo.com on the Investor Relations page.

Webcast URL (archived for 12 months): http://syrginfo.equisolvewebcast.com/q4-2016

About Synergy Resources Corporation

Synergy Resources Corporation is a domestic oil and natural gas exploration and production company. Synergy’s core area of operations is in the Wattenberg Field of the Denver-Julesburg Basin. The Denver-Julesburg Basin encompasses parts of Colorado, Wyoming, Kansas, and Nebraska. The Company’s corporate offices are located in Denver, Colorado. More company news and information about Synergy is available at www.syrginfo.com.

Important Cautions Regarding Forward Looking Statements

This press release contains forward-looking statements, within the meaning of the Private Securities Litigation Reform Act of 1995. All statements other than statements of historical fact are forward-looking statements. The use of words such as “believes”, “expects”, “anticipates”, “intends”, “plans”, “estimates”, “should”, “likely” or similar expressions, indicates a forward-looking statement. Forward-looking statements herein include statements regarding future production, capital projects and expenditures, drilling plans and growth. These statements are subject to risks and uncertainties and are based on the beliefs and assumptions of management, and information currently available to management. The actual results could differ materially from a conclusion, forecast or projection in the forward-looking information. Certain material factors or assumptions were applied in drawing a conclusion or making a forecast or projection as reflected in the forward-looking information. The identification in this press release of factors that may affect the Company’s future performance and the accuracy of forward-looking statements is meant to be illustrative and by no means exhaustive. All forward-looking statements should be evaluated with the understanding of their inherent uncertainty. Factors that could cause the Company’s actual results to differ materially from those expressed or implied by forward-looking statements include, but are not limited to: the success of the Company’s exploration and development efforts; the price of oil and gas; worldwide economic situation; change in interest rates or inflation; willingness and ability of third parties to honor their contractual commitments; the Company’s ability to raise additional capital, as it may be affected by current conditions in the stock market and competition in the oil and gas industry for risk capital; the Company’s capital costs, which may be affected by delays or cost overruns; costs of production; environmental and other regulations, as the same presently exist or may later be amended; the Company’s ability to identify, finance and integrate any future acquisitions; the volatility of the Company’s stock price; and the other factors described in the “Risk Factors” sections of the Company’s filings with the Securities and Exchange Commission, all of which are incorporated by reference in this release.

Reconciliation of Non-GAAP Financial Measures

We define adjusted EBITDA as net income (loss) adjusted to exclude the impact of the items set forth in the table below because these amounts can vary substantially from company to company within our industry depending upon accounting methods and book values of assets, capital structures, and the method by which the assets were acquired. We believe that adjusted EBITDA is widely used in our industry as a measure of operating performance and could also be used by investors to measure our ability to meet debt covenant requirements. The following table presents a reconciliation of adjusted EBITDA, a non-GAAP financial measure, to net income (loss), its nearest GAAP measure:

 
SYNERGY RESOURCES CORPORATION
RECONCILIATION OF NON-GAAP FINANCIAL MEASURES
(unaudited, in thousands)
         
  Three Months Ended December 31, Years Ended December 31,
  2016 2015 2016 2015
Adjusted EBITDA:                
  Net (loss) income $ 5,301   $ (48,187 ) $ (219,189 ) $ (131,689 )
  Depletion, depreciation, and accretion   13,677     13,840     46,678     62,071  
  Full cost ceiling impairment       41,890     215,223     141,230  
  Income tax expense (benefit)           106     (14,132 )
  Stock-based compensation   2,206     7,474     9,491     15,162  
  Mark-to-market of commodity derivative contracts:                
    Total (gain) loss on commodity derivative contracts   4,133     (5,340 )   7,750     (11,037 )
    Cash settlements on commodity derivative contracts   237     1,649     5,374     29,992  
    Cash premiums paid for commodity derivative contracts       (511 )       (5,073 )
  Interest expense (income)   (63 )   (43 )   (242 )   135  
      Adjusted EBITDA $ 25,491   $ 10,772   $ 65,191   $ 86,659  
                               

Consolidated Financial Statements

Condensed consolidated financial statements are included below. Additional financial information, including footnotes that are considered an integral part of the consolidated financial statements, can be found in Synergy’s Annual Report on Form 10-K for the period ended December 31, 2016, which is available at www.sec.gov.

 
SYNERGY RESOURCES CORPORATION
CONDENSED CONSOLIDATED BALANCE SHEETS
(unaudited; in thousands)
       
ASSETS December 31, 2016   December 31, 2015
Current assets:          
  Cash and cash equivalents $ 18,615     $ 66,499  
  Other current assets   35,569       33,199  
    Total current assets   54,184       99,698  
           
Oil and gas properties and other equipment   908,736       526,847  
Goodwill   40,711       40,711  
Other assets   20,482       5,360  
           
    Total assets $ 1,024,113     $ 672,616  
           
LIABILITIES AND SHAREHOLDERS’ EQUITY          
Current liabilities   92,240       74,706  
           
Revolving credit facility         78,000  
Notes payable, net of issuance costs   75,614        
Asset retirement obligations   13,775       13,400  
Other liabilities   1,745        
    Total liabilities   183,374       166,106  
           
Shareholders’ equity:          
  Common stock and paid-in capital   1,149,199       595,781  
  Retained deficit   (308,460 )     (89,271 )
Total shareholders’ equity   840,739       506,510  
           
Total liabilities and shareholders’ equity $ 1,024,113     $ 672,616  
               
 
SYNERGY RESOURCES CORPORATION
CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
(unaudited; in thousands)
 
  Year Ended December 31,
  2016   2015
Cash flows from operating activities:          
  Net loss $ (219,189 )   $ (131,689 )
  Adjustments to reconcile net loss to net cash provided by operating activities:          
    Depletion, depreciation, and accretion   46,678       62,071  
    Full cost ceiling impairment   215,223       141,230  
    Provision for deferred taxes         (14,130 )
    Other, non-cash items   22,615       29,044  
    Changes in operating assets and liabilities   (16,639 )     17,304  
    Net cash provided by operating activities   48,688       103,830  
           
Cash flows from investing activities:          
  Acquisitions of oil and gas properties and leaseholds   (511,173 )     (44,471 )
  Capital expenditures for drilling and completion activities   (119,571 )     (148,713 )
  Other capital expenditures   (7,044 )     (8,933 )
  Land and other property and equipment   (5,478 )     (447 )
  Cash held in escrow   (18,219 )      
  Net proceeds from sales of oil and gas properties and land   25,350       6,239  
    Net cash used in investing activities   (636,135 )     (196,325 )
           
Cash flows from financing activities:          
  Equity financing activities   542,722       187,444  
  Net debt financing activities   (3,159 )     (68,020 )
    Net cash provided by financing activities   539,563       119,424  
           
Net increase (decrease) in cash and equivalents   (47,884 )     26,929  
           
Cash and equivalents at beginning of period   66,499       39,570  
           
Cash and equivalents at end of period   18,615       66,499  
               
 
SYNERGY RESOURCES CORPORATION
CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS
(unaudited; in thousands, except share and per share data)
 
    Three Months Ended December 31,   Years Ended December 31,
    2016   2015   2016   2015
Oil and gas revenues   $ 38,695     $ 25,448     $ 107,149     $ 106,050  
                         
Expenses:                        
  Lease operating expenses     4,986       3,140       19,949       16,084  
  Production taxes     3,223       1,909       5,732       9,394  
  Depreciation, depletion, and accretion     13,677       13,840       46,678       62,071  
  Full cost ceiling impairment           41,890       215,223       141,230  
  Transportation commitment charge     92       2,802       597       2,802  
  General and administrative     7,346       15,437       30,545       31,192  
    Total expenses     29,324       79,018       318,724       262,773  
                         
Operating income (loss)     9,371       (53,570 )     (211,575 )     (156,723 )
                         
Other income (expense):                        
  Commodity derivatives gain (loss)     (4,133 )     5,340       (7,750 )     11,037  
  Interest income (expense), net     63       43       242       (135 )
    Total other income (expense)     (4,070 )     5,383       (7,508 )     10,902  
                         
Income (Loss) before income taxes     5,301       (48,187 )     (219,083 )     (145,821 )
                         
Income tax expense (benefit)                 106       (14,132 )
Net income (loss)   $ 5,301     $ (48,187 )   $ (219,189 )   $ (131,689 )
                         
Net income (loss) per common share:                        
  Basic   $ 0.03     $ (0.44 )   $ (1.26 )   $ (1.27 )
  Diluted   $ 0.03     $ (0.44 )   $ (1.26 )   $ (1.27 )
                         
Weighted-average shares outstanding:                        
  Basic     200,585,800       108,664,875       173,774,035       103,934,524  
  Diluted     201,254,678       108,664,875       173,774,035       103,934,524  
                                   

Synergy Resources Reports Fourth Quarter and Year End 2016 Financial and Operating Results; Announces Company Name, Address and Ticker Symbol Change

DENVER, CO–(Marketwired – February 23, 2017) – Synergy Resources Corporation (NYSE MKT: SYRG) (“Synergy”, the “Company”, “we”, “us” or “our”), a U.S. oil and gas exploration and production company focused on the Wattenberg Area of the Denver-Julesburg Basin, reports its fourth quarter and year-end financial and operating results for the period ended December 31, 2016, and announces a company name, address and ticker symbol change.

Fourth Quarter and Year End 2016 Highlights

  • Revenues were $38.7 million and $107.1 million for the three and twelve months ended December 31, 2016, respectively
  • Net income was $5.3 million or $0.03 per diluted share and net loss was $219.2 million or $1.26 per diluted share for the three and twelve months ended December 31, 2016, respectively
  • Adjusted EBITDA was $25.5 million and $65.2 million for the three and twelve months ended December 31, 2016, respectively (see further discussion regarding the presentation of adjusted EBITDA in “About Non-GAAP Financial Measures” below)

Fourth Quarter and Year End 2016 Financial Results

The following tables present certain per unit metrics that compare results of the corresponding quarterly reporting periods:

                 
    Three Months Ended       Year Ended    
Net Volumes   12/31/2016   12/31/2015   % Chg.   12/31/2016   12/31/2015   % Chg.
Crude Oil (MBbls)   705   552   28%   2,257   2,073   9%
Natural Gas (MMcf)   3,095   2,659   16%   12,086   8,472   43%
Sales Volumes: (MBOE)   1,221   995   23%   4,271   3,485   23%
Average Daily Volumes                        
Daily Production (BOE/day)   13,269   10,815   23%   11,670   9,548   22%
Product Price Received                        
Crude Oil ($/Bbl)   $40.94   $34.37   19%   $34.43   $40.08   (14)%
Natural Gas ($/Mcf)   $3.18   $2.44   30%   $2.44   $2.71   (10)%
Average Realized Price ($/BOE)   $31.70   $25.58   24%   $25.09   $30.43   (18)%
Per unit cost information                        
Lease Operating Expense ($/BOE)   4.08   3.16   29%   4.67   4.61   1%
Production Tax ($/BOE)   2.64   1.92   38%   1.34   2.70   (50)%
DD&A Expense ($/BOE)   11.20   13.91   (19)%   10.93   17.81   (39)%
Non-Cash G&A Expense ($/BOE)   1.81   7.59   (76)%   2.22   4.23   (48)%
Cash G&A Expense ($/BOE)   4.21   7.92   (47)%   4.93   4.72   4%
Total G&A Expense ($/BOE)   6.02   15.51   (61)%   7.15   8.95   (20)%
                         

The volatility of oil and natural gas prices impacted the Company’s financial results throughout the year. The Company’s fourth quarter benefited from higher prices relative to the same period a year ago as realized oil prices increased approximately 19%, averaging $40.94 per barrel versus $34.37 in the fourth quarter of 2015. Natural gas prices averaged $3.18 per Mcf in the fourth quarter of 2016 compared to $2.44 a year ago, a 30% increase. For the full year, however, realized oil prices averaged $34.43, 14% lower than the full year 2015, while natural gas prices averaged $2.44 per Mcf, 10% lower than 2015.

Revenues for the three months ended December 31, 2016 increased 52% as compared to the three months ended December 31, 2015. This was due to the higher commodity prices realized in the quarter versus the comparable period a year ago, along with a 23% increase in sales volumes period over period. For the twelve months ending December 31, 2016, despite a 23% increase in sales volumes year over year, revenues increased only 1% as the lower prices received for the year offset the production growth.

Production taxes for the twelve months ended December 31, 2016 were favorably impacted by an adjustment of the Company’s assumed ad valorem tax rate based on its most recent filing and areas of activity. G&A expense for the twelve months ended December 31, 2016 as compared to the twelve months ended December 31, 2015 declined by approximately $647 thousand and on a per unit of production basis by 20% year over year.

Net income for the three months ended December 31, 2016 totaled $5.3 million, or $0.03 per diluted share, as compared to a net loss of $48.2 million, or $0.44 per share, in the three months ended December 31, 2015. For the twelve months ended December 31, 2016 the Company reported a net loss of $219.2 million, or $1.26 per share, as compared to a net loss of $131.7 million, or $1.27 per share in the prior year. Net losses reported in both years 2016 and 2015 were primarily the result of ceiling test writedowns of $215 million and $141 million, respectively, related to commodity price weakness over those periods.

Adjusted EBITDA for the three and twelve months ended December 31, 2016 was $25.5 million and $65.2 million, respectively, compared to $10.8 million and $86.7 million for the same three- and twelve-month periods in 2015, respectively.

2016 Operating Activity

 
2016 Operating Activity
    # of Wells Drilled   # of Wells Completed & Turned to Sales
    (Gross)   (Net)   (Gross)   (Net)
Vista Pad   7   6   10   9
Fagerberg Pad   14   13   14   13
Evans Pad   22   21        
Williams Pad   7   7        
Kawata Pad   6   4        
Total wells   56   51   24   22
                 
2016 Gross Lateral Footage
Drilled ~ 450,000            
Completed ~ 146,000            
Wells in Progress at YE ’16 ~ 410,000            
                 
 
Fagerberg Pad
    Average Daily Production (Gross) *
Zone Well Count   Oil (Bls)   Gas (Mcf)   BOE /d (2-stream)
Niobrara 10   376   779   506
Codell 4   388   680   501
* First 90 days of production
 

Management Commentary

Lynn A. Peterson, Chairman and CEO of Synergy commented, “The Synergy team delivered outstanding performance during 2016. While some of the many changes in 2016 are less tangible, such as moving to a calendar year end and the strengthened independence of our Board of Directors, other changes, highlighted by our acquisition of the Greeley Crescent acreage and the development of infrastructure, are features of 2016 that we are reminded of every day. Our staff nearly doubled in 2016 providing the capacity to create and begin executing on a development plan that has set the stage for differentiated growth over the coming quarters and years. All of this and much more was accomplished while simultaneously maintaining a strong financial position along with the operational flexibility to react to changing commodity prices.”

Mr. Peterson also noted that, “As we continue to gain confidence in commodity prices, our plan is to maintain a two rig drilling program during 2017. As a result, we now believe that capital expenditures and production for 2017 should be at the top end of our guidance range issued in September 2016. We intend to provide updated 2017 guidance as we exit the first quarter of 2017 and observe the initial performance from some of the Evans wells. We are drilling out plugs in the second tranche of six Evans wells, and the wells have been turned to flowback as that process is completed. Stimulation activity is now focused on the next group of five Evans wells on the eastern pad.”

Company Name, Address and Ticker Symbol Change

The Company intends to propose that its shareholders approve a change in its legal name to “SRC Energy Inc.” at its 2017 annual meeting. Pending the shareholder vote on the proposal, the Company intends to use the new name on a “doing business as” basis beginning on or about March 6, 2017. In addition, the Company’s domain name will become SRCenergy.com. On or about March 6, 2017 the company’s NYSE MKT ticker symbol will change to SRCI.

Synergy will be relocating to its new offices effective February 27th, 2017. Our phone numbers will not be impacted by this change.

SRC Energy Inc.
1675 Broadway, Suite 2600
Denver, CO 80202

Conference Call

The Company will host a conference call on Friday, February 24, 2017 at 11:00 a.m. Eastern time (9:00 a.m. Mountain time) to discuss the results. The call will be conducted by Chairman and CEO Lynn A. Peterson, CFO James Henderson, COOs Nick Spence and Mike Eberhard, and Manager of IR John Richardson. A Q&A session will immediately follow the discussion of the results for the quarter. Please refer to Synergy’s website at www.syrginfo.com for the current corporate presentation and other news and information.

Dial-in (Toll-Free): (877) 407-9122

Dial-in (International): (201) 493-6747

Replay Information:

The Company’s earnings call will be available via Webcast. A link to the Webcast can be found at www.syrginfo.com on the Investor Relations page.

Webcast URL (archived for 12 months): http://syrginfo.equisolvewebcast.com/q4-2016

About Synergy Resources Corporation

Synergy Resources Corporation is a domestic oil and natural gas exploration and production company. Synergy’s core area of operations is in the Wattenberg Field of the Denver-Julesburg Basin. The Denver-Julesburg Basin encompasses parts of Colorado, Wyoming, Kansas, and Nebraska. The Company’s corporate offices are located in Denver, Colorado. More company news and information about Synergy is available at www.syrginfo.com.

Important Cautions Regarding Forward Looking Statements

This press release contains forward-looking statements, within the meaning of the Private Securities Litigation Reform Act of 1995. All statements other than statements of historical fact are forward-looking statements. The use of words such as “believes”, “expects”, “anticipates”, “intends”, “plans”, “estimates”, “should”, “likely” or similar expressions, indicates a forward-looking statement. Forward-looking statements herein include statements regarding future production, capital projects and expenditures, drilling plans and growth. These statements are subject to risks and uncertainties and are based on the beliefs and assumptions of management, and information currently available to management. The actual results could differ materially from a conclusion, forecast or projection in the forward-looking information. Certain material factors or assumptions were applied in drawing a conclusion or making a forecast or projection as reflected in the forward-looking information. The identification in this press release of factors that may affect the Company’s future performance and the accuracy of forward-looking statements is meant to be illustrative and by no means exhaustive. All forward-looking statements should be evaluated with the understanding of their inherent uncertainty. Factors that could cause the Company’s actual results to differ materially from those expressed or implied by forward-looking statements include, but are not limited to: the success of the Company’s exploration and development efforts; the price of oil and gas; worldwide economic situation; change in interest rates or inflation; willingness and ability of third parties to honor their contractual commitments; the Company’s ability to raise additional capital, as it may be affected by current conditions in the stock market and competition in the oil and gas industry for risk capital; the Company’s capital costs, which may be affected by delays or cost overruns; costs of production; environmental and other regulations, as the same presently exist or may later be amended; the Company’s ability to identify, finance and integrate any future acquisitions; the volatility of the Company’s stock price; and the other factors described in the “Risk Factors” sections of the Company’s filings with the Securities and Exchange Commission, all of which are incorporated by reference in this release.

Reconciliation of Non-GAAP Financial Measures

We define adjusted EBITDA as net income (loss) adjusted to exclude the impact of the items set forth in the table below because these amounts can vary substantially from company to company within our industry depending upon accounting methods and book values of assets, capital structures, and the method by which the assets were acquired. We believe that adjusted EBITDA is widely used in our industry as a measure of operating performance and could also be used by investors to measure our ability to meet debt covenant requirements. The following table presents a reconciliation of adjusted EBITDA, a non-GAAP financial measure, to net income (loss), its nearest GAAP measure:

 
SYNERGY RESOURCES CORPORATION
RECONCILIATION OF NON-GAAP FINANCIAL MEASURES
(unaudited, in thousands)
         
  Three Months Ended December 31, Years Ended December 31,
  2016 2015 2016 2015
Adjusted EBITDA:                
  Net (loss) income $ 5,301   $ (48,187 ) $ (219,189 ) $ (131,689 )
  Depletion, depreciation, and accretion   13,677     13,840     46,678     62,071  
  Full cost ceiling impairment       41,890     215,223     141,230  
  Income tax expense (benefit)           106     (14,132 )
  Stock-based compensation   2,206     7,474     9,491     15,162  
  Mark-to-market of commodity derivative contracts:                
    Total (gain) loss on commodity derivative contracts   4,133     (5,340 )   7,750     (11,037 )
    Cash settlements on commodity derivative contracts   237     1,649     5,374     29,992  
    Cash premiums paid for commodity derivative contracts       (511 )       (5,073 )
  Interest expense (income)   (63 )   (43 )   (242 )   135  
      Adjusted EBITDA $ 25,491   $ 10,772   $ 65,191   $ 86,659  
                               

Consolidated Financial Statements

Condensed consolidated financial statements are included below. Additional financial information, including footnotes that are considered an integral part of the consolidated financial statements, can be found in Synergy’s Annual Report on Form 10-K for the period ended December 31, 2016, which is available at www.sec.gov.

 
SYNERGY RESOURCES CORPORATION
CONDENSED CONSOLIDATED BALANCE SHEETS
(unaudited; in thousands)
       
ASSETS December 31, 2016   December 31, 2015
Current assets:          
  Cash and cash equivalents $ 18,615     $ 66,499  
  Other current assets   35,569       33,199  
    Total current assets   54,184       99,698  
           
Oil and gas properties and other equipment   908,736       526,847  
Goodwill   40,711       40,711  
Other assets   20,482       5,360  
           
    Total assets $ 1,024,113     $ 672,616  
           
LIABILITIES AND SHAREHOLDERS’ EQUITY          
Current liabilities   92,240       74,706  
           
Revolving credit facility         78,000  
Notes payable, net of issuance costs   75,614        
Asset retirement obligations   13,775       13,400  
Other liabilities   1,745        
    Total liabilities   183,374       166,106  
           
Shareholders’ equity:          
  Common stock and paid-in capital   1,149,199       595,781  
  Retained deficit   (308,460 )     (89,271 )
Total shareholders’ equity   840,739       506,510  
           
Total liabilities and shareholders’ equity $ 1,024,113     $ 672,616  
               
 
SYNERGY RESOURCES CORPORATION
CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
(unaudited; in thousands)
 
  Year Ended December 31,
  2016   2015
Cash flows from operating activities:          
  Net loss $ (219,189 )   $ (131,689 )
  Adjustments to reconcile net loss to net cash provided by operating activities:          
    Depletion, depreciation, and accretion   46,678       62,071  
    Full cost ceiling impairment   215,223       141,230  
    Provision for deferred taxes         (14,130 )
    Other, non-cash items   22,615       29,044  
    Changes in operating assets and liabilities   (16,639 )     17,304  
    Net cash provided by operating activities   48,688       103,830  
           
Cash flows from investing activities:          
  Acquisitions of oil and gas properties and leaseholds   (511,173 )     (44,471 )
  Capital expenditures for drilling and completion activities   (119,571 )     (148,713 )
  Other capital expenditures   (7,044 )     (8,933 )
  Land and other property and equipment   (5,478 )     (447 )
  Cash held in escrow   (18,219 )      
  Net proceeds from sales of oil and gas properties and land   25,350       6,239  
    Net cash used in investing activities   (636,135 )     (196,325 )
           
Cash flows from financing activities:          
  Equity financing activities   542,722       187,444  
  Net debt financing activities   (3,159 )     (68,020 )
    Net cash provided by financing activities   539,563       119,424  
           
Net increase (decrease) in cash and equivalents   (47,884 )     26,929  
           
Cash and equivalents at beginning of period   66,499       39,570  
           
Cash and equivalents at end of period   18,615       66,499  
               
 
SYNERGY RESOURCES CORPORATION
CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS
(unaudited; in thousands, except share and per share data)
 
    Three Months Ended December 31,   Years Ended December 31,
    2016   2015   2016   2015
Oil and gas revenues   $ 38,695     $ 25,448     $ 107,149     $ 106,050  
                         
Expenses:                        
  Lease operating expenses     4,986       3,140       19,949       16,084  
  Production taxes     3,223       1,909       5,732       9,394  
  Depreciation, depletion, and accretion     13,677       13,840       46,678       62,071  
  Full cost ceiling impairment           41,890       215,223       141,230  
  Transportation commitment charge     92       2,802       597       2,802  
  General and administrative     7,346       15,437       30,545       31,192  
    Total expenses     29,324       79,018       318,724       262,773  
                         
Operating income (loss)     9,371       (53,570 )     (211,575 )     (156,723 )
                         
Other income (expense):                        
  Commodity derivatives gain (loss)     (4,133 )     5,340       (7,750 )     11,037  
  Interest income (expense), net     63       43       242       (135 )
    Total other income (expense)     (4,070 )     5,383       (7,508 )     10,902  
                         
Income (Loss) before income taxes     5,301       (48,187 )     (219,083 )     (145,821 )
                         
Income tax expense (benefit)                 106       (14,132 )
Net income (loss)   $ 5,301     $ (48,187 )   $ (219,189 )   $ (131,689 )
                         
Net income (loss) per common share:                        
  Basic   $ 0.03     $ (0.44 )   $ (1.26 )   $ (1.27 )
  Diluted   $ 0.03     $ (0.44 )   $ (1.26 )   $ (1.27 )
                         
Weighted-average shares outstanding:                        
  Basic     200,585,800       108,664,875       173,774,035       103,934,524  
  Diluted     201,254,678       108,664,875       173,774,035       103,934,524  
                                   

Nutrafuels, Inc. (NTFU: OTC Pink Current) | NutraFuels, Inc. (NTFU) Announces Further Steps for Initiation of Clinical Trials with the Company’s Product Line of Oral Spray Nutraceuticals

COCONUT CREEK, FL–(Marketwired – February 23, 2017) – NutraFuels, Inc. (“NutraFuels” or “NTFU”), (OTC PINK: NTFU), today announced that the company as part of the implementation of initiation of clinical studies on the company’s product line of oral spray nutraceuticals has announced the appointment of Kenneth Duchin, Ph.D. as Vice-President Clinical Development and the agreement with Palm Beach Research to conduct clinical studies.

The recent growth of NutraFuels has provided the opportunity to explore the benefits of the oral spray product line. Dr Duchin’s career has spanned over 30 years in the pharmaceutical industry in various management positions at Bristol-Myers Squibb and in small and mid-size companies (Theravance, IVAX Corporation, Noven Pharmaceuticals) as well as in start-up virtual organizations. He has extensive drug development experience in a broad range of therapeutic areas, has led several registration programs, authored regulatory NDA and ANDA documents and has led cross-functional development teams. In addition, he has been an inventor of 9 patents and has published nearly 40 papers in peer reviewed journals.

To facilitate the clinical investigations sponsored by Nutrafuels, the company has engaged Palm Beach Research, West Palm Beach FL to conduct the clinical studies. This facility has access to large numbers of patients who routinely participate in clinical trials for many pharmaceutical and biotech companies based in the US and abroad.

“We are very pleased to be working with Ken and Palm Beach Research to initiate clinical trials for our health and wellness products,” said Edgar Ward, NutraFuels President/CEO.

About Palm Beach Research Center

Since 1994, Palm Beach Research Center has been dedicated to advancing the development of new investigational treatments (drugs, devices) to benefit mankind by assisting pharmaceutical companies in research and eventual FDA approval for public availability. Our experienced research team is designed to streamline efforts to assure maximum efficiency.

Palm Beach Research Center is located in its own building, on the corner of Palm Beach Lakes Boulevard and Okeechobee Boulevard, just west of I-95. The center is almost 7,000 square feet of dedicated research space. There are separate branches for patient recruitment, regulatory, quality assurance, and patient screening in addition to eight full time, clinical research coordinators.

Community support remains outstanding and our database is extensive coming from our unique geographical area, which is comprised of a wide range of age, gender and ethnic backgrounds. These numbers are increasing, as Palm Beach County is one of the fastest growing areas of our country.

Palm Beach Research Center’s track record of study enrollment has created a large amount of repeat business. However, Palm Beach Research Center is constantly searching out new partnerships in the quest to work on new medications and treatments seeking FDA approval.

Palm Beach Research is honored to continue a relationship, and form a strategic partnership, with NutraFuels, Inc.

About NutraFuels, Inc.

http://nutrafuels.com/

NTFU was founded in 2010, to manufacture, distribute and market a line of oral spray nutritional dietary products to consumers, retailers and wholesale outlets. Oral spray delivery systems are recognized by many as an effective methodology for delivery of pharmaceutical and nutraceutical products. Oral spray delivery is recognized by consumers for its convenience, dosage precision and timely assimilation into the body. NTFU’s product line consists of vitamins and nutrients in an aqueous solution, orally delivered through a non-aerosol pump. NTFU’s products are sprayed into the mouth in the form of a fine mist entering the delicate tissue of the mouth. The nutrients are delivered into the bloodstream and assimilated throughout the body more quickly than traditional methods, avoiding the solubility and absorption problems common with most ingested vitamins and nutritional supplements in pill or capsule form.

Safe Harbor

This press release contains forward-looking statements, particularly as related to, among other things, the business plans of NutraFuels, Inc statements relating to goals, plans and projections regarding the NutraFuels’ financial position and business strategy. The words or phrases “would be,” “will allow,” “intends to,” “may result,” “are expected to,” “will continue,” “anticipates,” “expects,” “estimate,” “project,” “indicate,” “could,” “potentially,” “should,” “believe,” “think”, “considers” or similar expressions are intended to identify “forward-looking statements.” These forward-looking statements fall within the meaning of Section 27A of the Securities Act of 1933 and Section 21E of the Securities Act of 1934 and are subject to the safe harbor created by these sections. Actual results could differ materially from those projected in the forward-looking statements as a result of a number of risks and uncertainties. Such forward-looking statements are based on current expectations, involve known and unknown risks, a reliance on third parties for information, transactions or orders that may be cancelled, and other factors that may cause our actual results, performance or achievements, or developments in our industry, to differ materially from the anticipated results, performance or achievements expressed or implied by such forward-looking statements. Factors that could cause actual results to differ materially from anticipated results include risks and uncertainties related to the fluctuation of global economic conditions, the performance of management and our employees, our ability to obtain financing, competition, general economic conditions and other factors that are detailed in our periodic reports and on documents we file from time to time with the Securities and Exchange Commission. Statements made herein are as of the date of this press release and should not be relied upon as of any subsequent date. NutraFuels cautions readers not to place undue reliance on such statements. NutraFuels does not undertake, and NutraFuels specifically disclaims any obligation, to update any forward-looking statements to reflect occurrences, developments, unanticipated events or circumstances after the date of such statement. Actual results may differ materially from NutraFuels’ expectations and estimates.

Copyright © 2017 Marketwired. All Rights Reserved

The above news release has been provided by the above company via the OTC Disclosure and News Service. Issuers of news releases and not OTC Markets Group Inc. are solely responsible for the accuracy of such news releases.

NextEra Energy Partners, LP files Annual Report on Form 10-K

JUNO BEACH, Fla., Feb. 23, 2017 /PRNewswire/ — NextEra Energy Partners, LP (NYSE: NEP) today announced that it has filed its Annual Report on Form 10-K for the fiscal year ended Dec. 31, 2016, with the U.S. Securities and Exchange Commission (SEC). The report can be found on the SEC Filings page of the NextEra Energy Partners website at http://www.Investor.NextEraEnergyPartners.com/. A hard copy of the partnership’s complete 2016 full-year audited financial statements is available upon request, free of charge, by contacting Investor Relations.

NextEra Energy Partners, LP NextEra Energy Partners, LP (NYSE: NEP) is a growth-oriented limited partnership formed by NextEra Energy, Inc. (NYSE: NEE) to acquire, manage and own contracted clean energy projects with stable, long-term cash flows. Headquartered in Juno Beach, Florida, NextEra Energy Partners owns interests in wind and solar projects in North America, as well as natural gas infrastructure assets in Texas. The renewable energy projects are fully contracted, use industry-leading technology and are located in regions that are favorable for generating energy from the wind and sun. The seven natural gas pipelines in the portfolio are all strategically located, serving power producers and municipalities in South Texas, processing plants and producers in the Eagle Ford Shale, and commercial and industrial customers in the Houston area. The NET Mexico Pipeline, the largest pipeline in the portfolio, provides a critical source of natural gas transportation for low-cost, U.S.-sourced shale gas to Mexico. For more information about NextEra Energy Partners, please visit: www.NextEraEnergyPartners.com.

SOURCE NextEra Energy Partners, LP

Alon USA Energy Reports Fourth Quarter and Full Year 2016 Results

DALLAS, Feb. 23, 2017 /PRNewswire/ — Alon USA Energy, Inc. (NYSE: ALJ) (“Alon”) today announced results for the fourth quarter and year ended December 31, 2016. Net loss available to stockholders for the fourth quarter of 2016 was $(18.1) million, or $(0.25) per share, compared to net loss available to stockholders of $(52.5) million, or $(0.75) per share, for the same period last year. Excluding special items, Alon recorded net loss available to stockholders of $(14.3) million, or $(0.20) per share, for the fourth quarter of 2016, compared to net loss available to stockholders of $(14.6) million, or $(0.21) per share, for the same period last year.

Net loss available to stockholders for the full year 2016 was $(82.8) million, or $(1.17) per share, compared to net income available to stockholders of $52.8 million, or $0.76 per share, for 2015. Excluding special items, Alon recorded net loss available to stockholders of $(65.1) million, or $(0.92) per share, for the full year 2016, compared to net income available to stockholders of $95.5 million, or $1.37 per share, for 2015.

As previously announced, in January 2017, Delek US and Alon entered into a definitive agreement under which Delek will acquire the outstanding shares of Alon common stock that Delek does not already own in an all-stock transaction. The transaction is expected to close in the first half of 2017, subject to customary closing conditions, including regulatory approval and approval by Delek US shareholders and Alon shareholders. We believe the economies of scale, financial strength and synergies generated through this merger create the opportunity to drive long-term value for shareholders.

In February 2017, the Krotz Springs refinery received approval from the EPA for a small refinery exemption from the requirements of the renewable fuel standard for the 2016 calendar year. As a result, we expect to book a reduction in RINs expense of $29.0 million in the first quarter of 2017, based on a weighted average RINs price per gallon of $0.58.

Alan Moret, CEO, commented, “Our diversification proved to be an asset for us in 2016, as positive contributions from our asphalt segment, retail segment and our renewable fuels facility in California helped offset the impact of weak crack spreads, high RIN prices and narrower crude differentials on our refining results. Our asphalt business operating income more than doubled in 2016 relative to 2015, as sales volumes increased by 19 percent and direct operating expenses were reduced by 8 percent. Our renewable fuels facility, which began operations in February 2016, produced approximately 30 million gallons of renewable fuel in 2016. We have been encouraged by the improvement in refining fundamentals that we saw at the end of 2016 and into 2017, including the widening of domestic crude discounts relative to Brent. We also are pleased to see RIN prices decline.

“The Big Spring refinery ran well in the fourth quarter, achieving total throughput of almost 77,000 barrels per day. The refinery also set a new quarterly record by processing over 44,000 barrels per day of WTI Midland in the quarter, further demonstrating the flexibility of the asset. The fourth quarter refinery operating margin of $7.65 per barrel is net of a negative impact of approximately $1.10 per barrel related to RINs costs. Operating expense in the quarter was low at $3.39 per barrel. As we’ve said before, we do not expect any major maintenance at Big Spring in 2017. We expect total throughput at the Big Spring refinery to average 77,000 barrels per day for the first quarter of 2017 and 75,000 barrels per day for the full year of 2017.

“The Krotz Springs refinery also ran well in the fourth quarter with total throughput of 70,000 barrels per day. The refinery operating margin of $3.40 per barrel was negatively impacted by approximately $1.60 per barrel due to the high cost of RINs. Operating expense in the fourth quarter was low at $3.44 per barrel. We expect total throughput at the Krotz Springs refinery to average 77,000 barrels per day for the first quarter of 2017 and 74,000 barrels per day for the full year of 2017.

“Our asphalt business performed exceptionally well in what is typically a seasonally weak quarter. Asphalt operating income of $3.2 million in the fourth quarter was driven by sales volumes of 133 thousand tons and an attractive margin of $108 per ton.

“Our renewable fuels facility in California had its most profitable quarter since operations began, generating $9 million of operating income in the fourth quarter. This was achieved in spite of reduced throughput of 2,400 barrels per day due to maintenance being done by a third-party supplier in the quarter. We expect total throughput at our renewable fuels facility to average 2,500 barrels per day for the first quarter of 2017 and 2,600 barrels per day for the full year of 2017.

“Our retail results were negatively impacted by seasonal weakness and continued economic headwinds in the Permian Basin. That said, we are encouraged by the increase in rig activity in the Permian, and we believe our retail segment is well positioned to benefit as the West Texas economy improves.”

FOURTH QUARTER 2016

Special items increased net loss by $3.8 million for the fourth quarter of 2016 primarily as a result of employee retention expenses of $2.0 million, unrealized losses of $3.8 million associated with commodity swaps, losses of $0.7 million related to an asphalt inventory adjustment and $0.1 million associated with losses recognized on disposition of assets, before income tax and non-controlling interest impacts of $2.8 million. Special items reduced net income by $37.9 million for the fourth quarter of 2015 primarily as a result of a loss on impairment of goodwill of $39.0 million, losses of $1.7 million related to an asphalt inventory adjustment, employee retention expenses of $1.3 million and unrealized losses of $1.1 million associated with commodity swaps, partially offset by insurance recoveries net of professional fees of $3.6 million and $1.3 million associated with gains recognized on disposition of assets, before income tax and non-controlling interest impacts of $0.2 million.

The combined total refinery average throughput for the fourth quarter of 2016 was 146,725 barrels per day (“bpd”), compared to a combined total refinery average throughput of 116,995 bpd for the fourth quarter of 2015. The Big Spring refinery average throughput for the fourth quarter of 2016 was 76,654 bpd, compared to 75,925 bpd for the fourth quarter of 2015. The Krotz Springs refinery average throughput for the fourth quarter of 2016 was 70,071 bpd, compared to 41,070 bpd for the fourth quarter of 2015. During the fourth quarter of 2016, the Krotz Springs refinery throughput was impacted by our election to reduce the crude rate in order to optimize the refinery yield. During the fourth quarter of 2015, throughput at our Krotz Springs refinery was lower as a result of downtime necessary to complete the planned major turnaround.

Refinery operating margin at the Big Spring refinery was $7.65 per barrel for the fourth quarter of 2016 compared to $10.02 per barrel for the same period in 2015. This decrease in operating margin was primarily due to increased RINs costs, a reduced benefit from the contango market environment which increased the cost of crude and unfavorable differences in Group III to Gulf Coast gasoline and diesel prices in the fourth quarter of 2016 compared to the same period in 2015.

Refinery operating margin at the Krotz Springs refinery was $3.40 per barrel for the fourth quarter of 2016 compared to $1.55 per barrel for the same period in 2015. During the fourth quarter of 2016, the Krotz Springs operating margin was favorably impacted by a higher Gulf Coast 2/1/1 high sulfur diesel crack spread and a widening of the WTI Cushing to WTI Midland spread, partially offset by a narrowing of the LLS to WTI Cushing spread, increased RINs costs and a reduced benefit from the contango market environment which increased the cost of crude. During the fourth quarter of 2015, the Krotz Springs operating margin reflects the negative impact of the planned major turnaround on refinery production.

The average Gulf Coast 3/2/1 crack spread was $12.83 per barrel for the fourth quarter of 2016 compared to $10.90 per barrel for the fourth quarter of 2015. The average Gulf Coast 2/1/1 high sulfur diesel crack spread was $8.63 per barrel for the fourth quarter of 2016 compared to $7.13 per barrel for the fourth quarter of 2015.

The average WTI Cushing to WTI Midland spread for the fourth quarter of 2016 was $0.25 per barrel compared to $(0.20) per barrel for the same period in 2015. The average WTI Cushing to WTS spread for the fourth quarter of 2016 was $1.33 per barrel compared to $(0.26) per barrel for the same period in 2015. The average LLS to WTI Cushing spread for the fourth quarter of 2016 was $1.42 per barrel compared to $2.08 per barrel for the same period in 2015. The average Brent to WTI Cushing spread for the fourth quarter of 2016 was $(0.20) per barrel compared to $1.35 per barrel for the same period in 2015. The average Brent to LLS spread for the fourth quarter of 2016 was $(1.36) per barrel compared to $(0.30) per barrel for the same period in 2015.

The average RINs cost effect on the Big Spring refinery operating margin was $1.08 per barrel for the fourth quarter of 2016, compared to $0.45 per barrel for the fourth quarter of 2015. The average RINs cost effect on the Krotz Springs refinery operating margin was $1.58 per barrel for the fourth quarter of 2016, compared to $0.60 per barrel for the fourth quarter of 2015.

The contango environment in the fourth quarter of 2016 created an average cost of crude benefit of $0.79 per barrel compared to an average cost of crude benefit of $0.94 per barrel for the same period in 2015.

For the fourth quarter of 2016, our California renewable fuels facility generated an operating margin of $70.57 per barrel from an average of 2,409 barrels per day of throughput. Our statements of operations include operating income of $8.7 million for the fourth quarter of 2016 related to the facility’s operations.

Asphalt margins for the fourth quarter of 2016 were $107.89 per ton compared to $102.85 per ton for the fourth quarter of 2015. On a cash basis (i.e. excluding inventory effects), asphalt margins in the fourth quarter of 2016 were $116.06 per ton compared to $106.92 per ton in the fourth quarter of 2015.

Retail fuel margins decreased to 18.5 cents per gallon in the fourth quarter of 2016 from 20.0 cents per gallon in the fourth quarter of 2015. Retail fuel sales volume increased to 54.0 million gallons in the fourth quarter of 2016 from 52.2 million gallons in the fourth quarter of 2015. Merchandise margins decreased to 30.5% in the fourth quarter of 2016 from 31.1% in the fourth quarter of 2015. Merchandise sales decreased to $78.9 million in the fourth quarter of 2016 from $81.0 million in the fourth quarter of 2015.

FULL-YEAR 2016

Special items increased net loss by $17.7 million for 2016 primarily as a result of employee retention expenses of $10.7 million, losses of $1.0 million related to an asphalt inventory adjustment, unrealized losses of $14.8 million associated with commodity swaps and $1.7 million associated with losses recognized on disposition of assets, before income tax and non-controlling interest impacts of $10.5 million. Special items reduced net income by $42.7 million for 2015 primarily as a result of a loss on impairment of goodwill of $39.0 million, losses of $8.1 million related to an asphalt inventory adjustment and employee retention expenses of $11.3 million, partially offset by unrealized gains of $7.9 million associated with commodity swaps, insurance recoveries net of professional fees of $3.6 million and $1.9 million associated with gains recognized on disposition of assets, before income tax and non-controlling interest impacts of $2.3 million.

Combined refinery average throughput for 2016 was 139,243 bpd, compared to a combined refinery average throughput of 140,036 bpd in 2015. The Big Spring refinery average throughput for 2016 was 71,363 bpd compared to 74,906 bpd for 2015. The reduced throughput at our Big Spring refinery during 2016 was the result of a reformer regeneration during the first quarter of 2016 and third quarter of 2016. Additionally, throughput was reduced as a result of a catalyst replacement for our diesel hydrotreater unit in the first quarter of 2016 and unplanned downtime during the second quarter of 2016 due to a power outage caused by inclement weather, which affected multiple units. The Krotz Springs refinery average throughput for 2016 was 67,880 bpd compared to 65,130 bpd for 2015. During 2016, the Krotz Springs refinery throughput was impacted by our election to reduce the crude rate in order to optimize the refinery yield, as well as maintenance that was performed on the fluid catalytic cracking unit during the second quarter of 2016. During 2015, we completed the planned major turnaround at the Krotz Springs refinery, which reduced throughput during the period.

Refinery operating margin at the Big Spring refinery was $8.28 per barrel for 2016 compared to $14.43 per barrel for 2015. This decrease in operating margin was primarily due to a lower Gulf Coast 3/2/1 crack spread, a narrowing of the WTI Cushing to WTI Midland spread and increased RINs costs, partially offset by a widening of the WTI Cushing to WTS spread and an increased benefit from the contango market environment which reduced the cost of crude.

Refinery operating margin at the Krotz Springs refinery was $3.06 per barrel for 2016 compared to $7.02 per barrel for 2015. This decrease in operating margin was primarily due to a lower Gulf Coast 2/1/1 high sulfur diesel crack spread, a narrowing of both the WTI Cushing to WTI Midland and the LLS to WTI Cushing spreads and increased RINs costs, partially offset by an increased benefit from the contango market environment which reduced the cost of crude.

The average Gulf Coast 3/2/1 crack spread for 2016 was $12.64 per barrel compared to $17.02 per barrel for 2015. The average Gulf Coast 2/1/1 high sulfur diesel crack spread for 2016 was $7.95 per barrel compared to $10.81 per barrel for 2015.

The average WTI Cushing to WTI Midland spread for 2016 was $0.15 per barrel compared to $0.39 per barrel for 2015. The average WTI Cushing to WTS spread for 2016 was $0.73 per barrel compared to $(0.06) per barrel for 2015. The average LLS to WTI Cushing spread for 2016 was $1.70 per barrel compared to $3.73 per barrel for 2015. The average Brent to WTI Cushing spread for 2016 was $0.21 per barrel compared to $3.54 per barrel for 2015. The average Brent to LLS spread for 2016 was $(1.45) per barrel compared to $0.14 per barrel for 2015.

The average RINs cost effect on the Big Spring refinery operating margin was $0.55 per barrel for 2016, compared to $0.42 per barrel for 2015. The average RINs cost effect on the Krotz Springs refinery operating margin was $1.48 per barrel for 2016, compared to $0.99 per barrel for 2015.

The contango environment in 2016 created an average cost of crude benefit of $1.24 per barrel compared to an average cost of crude benefit of $1.01 per barrel in 2015.

During 2016, our California renewable fuels facility generated an operating margin of $68.67 per barrel from an average of 2,275 barrels per day of throughput. Our statements of operations include operating income of $24.1 million in 2016 related to the facility’s operations.

Asphalt margins for 2016 were $98.80 per ton compared to $105.70 per ton in 2015. On a cash basis (i.e. excluding inventory effects), asphalt margins in 2016 were $100.94 per ton compared to $109.35 per ton in 2015.

Retail fuel margins decreased to 19.8 cents per gallon in 2016 from 21.3 cents per gallon in 2015. Retail fuel sales volume increased to 209.0 million gallons in 2016 from 199.1 million gallons in 2015. Merchandise margins decreased to 31.2% in 2016 from 31.9% in 2015. Merchandise sales decreased to $324.4 million in 2016 from $328.5 million in 2015.

Alon also announced today that its Board of Directors has declared the regular quarterly cash dividend of $0.15 per share. The dividend is payable on March 17, 2017 to stockholders of record at the close of business on March 9, 2017.

CONFERENCE CALL

Alon has scheduled a conference call, which will be broadcast live over the Internet on Friday, February 24, 2017, at 11:30 a.m. Eastern Time (10:30 a.m. Central Time), to discuss the fourth quarter and year-end 2016 financial results. To access the call, please dial 877-407-0672, or 412-902-0003 for international callers, and ask for the Alon USA Energy call at least 10 minutes prior to the start time. Investors may also listen to the conference live by logging on to the Alon investor relations website, http://ir.alonusa.com. A telephonic replay of the conference call will be available through March 3, 2017, and may be accessed by calling 877-660-6853, or 201-612-7415 for international callers, and using the passcode 13652999#. A webcast archive will also be available at http://ir.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. Alon owns 100% of the general partner and 81.6% of the limited partner interests in Alon USA Partners, LP (NYSE: ALDW), which owns a crude oil refinery in Big Spring, Texas, with a crude oil throughput capacity of 73,000 barrels per day and an integrated wholesale marketing business. In addition, Alon directly owns a crude oil refinery in Krotz Springs, Louisiana, with a crude oil throughput capacity of 74,000 barrels per day. Alon also owns crude oil refineries in California, which have not processed crude oil since 2012. Alon owns a majority interest in a renewable fuels facility in California, with a throughput capacity of 3,000 barrels per day. Alon is a leading marketer of asphalt, which it distributes primarily through asphalt terminals located predominately in the Southwestern and Western United States. Alon is the largest 7-Eleven licensee in the United States and operates approximately 300 convenience stores which also market motor fuels in Central and West 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.

 

SOURCE Alon USA Energy, Inc.

Alon USA Energy Reports Fourth Quarter and Full Year 2016 Results

DALLAS, Feb. 23, 2017 /PRNewswire/ — Alon USA Energy, Inc. (NYSE: ALJ) (“Alon”) today announced results for the fourth quarter and year ended December 31, 2016. Net loss available to stockholders for the fourth quarter of 2016 was $(18.1) million, or $(0.25) per share, compared to net loss available to stockholders of $(52.5) million, or $(0.75) per share, for the same period last year. Excluding special items, Alon recorded net loss available to stockholders of $(14.3) million, or $(0.20) per share, for the fourth quarter of 2016, compared to net loss available to stockholders of $(14.6) million, or $(0.21) per share, for the same period last year.

Net loss available to stockholders for the full year 2016 was $(82.8) million, or $(1.17) per share, compared to net income available to stockholders of $52.8 million, or $0.76 per share, for 2015. Excluding special items, Alon recorded net loss available to stockholders of $(65.1) million, or $(0.92) per share, for the full year 2016, compared to net income available to stockholders of $95.5 million, or $1.37 per share, for 2015.

As previously announced, in January 2017, Delek US and Alon entered into a definitive agreement under which Delek will acquire the outstanding shares of Alon common stock that Delek does not already own in an all-stock transaction. The transaction is expected to close in the first half of 2017, subject to customary closing conditions, including regulatory approval and approval by Delek US shareholders and Alon shareholders. We believe the economies of scale, financial strength and synergies generated through this merger create the opportunity to drive long-term value for shareholders.

In February 2017, the Krotz Springs refinery received approval from the EPA for a small refinery exemption from the requirements of the renewable fuel standard for the 2016 calendar year. As a result, we expect to book a reduction in RINs expense of $29.0 million in the first quarter of 2017, based on a weighted average RINs price per gallon of $0.58.

Alan Moret, CEO, commented, “Our diversification proved to be an asset for us in 2016, as positive contributions from our asphalt segment, retail segment and our renewable fuels facility in California helped offset the impact of weak crack spreads, high RIN prices and narrower crude differentials on our refining results. Our asphalt business operating income more than doubled in 2016 relative to 2015, as sales volumes increased by 19 percent and direct operating expenses were reduced by 8 percent. Our renewable fuels facility, which began operations in February 2016, produced approximately 30 million gallons of renewable fuel in 2016. We have been encouraged by the improvement in refining fundamentals that we saw at the end of 2016 and into 2017, including the widening of domestic crude discounts relative to Brent. We also are pleased to see RIN prices decline.

“The Big Spring refinery ran well in the fourth quarter, achieving total throughput of almost 77,000 barrels per day. The refinery also set a new quarterly record by processing over 44,000 barrels per day of WTI Midland in the quarter, further demonstrating the flexibility of the asset. The fourth quarter refinery operating margin of $7.65 per barrel is net of a negative impact of approximately $1.10 per barrel related to RINs costs. Operating expense in the quarter was low at $3.39 per barrel. As we’ve said before, we do not expect any major maintenance at Big Spring in 2017. We expect total throughput at the Big Spring refinery to average 77,000 barrels per day for the first quarter of 2017 and 75,000 barrels per day for the full year of 2017.

“The Krotz Springs refinery also ran well in the fourth quarter with total throughput of 70,000 barrels per day. The refinery operating margin of $3.40 per barrel was negatively impacted by approximately $1.60 per barrel due to the high cost of RINs. Operating expense in the fourth quarter was low at $3.44 per barrel. We expect total throughput at the Krotz Springs refinery to average 77,000 barrels per day for the first quarter of 2017 and 74,000 barrels per day for the full year of 2017.

“Our asphalt business performed exceptionally well in what is typically a seasonally weak quarter. Asphalt operating income of $3.2 million in the fourth quarter was driven by sales volumes of 133 thousand tons and an attractive margin of $108 per ton.

“Our renewable fuels facility in California had its most profitable quarter since operations began, generating $9 million of operating income in the fourth quarter. This was achieved in spite of reduced throughput of 2,400 barrels per day due to maintenance being done by a third-party supplier in the quarter. We expect total throughput at our renewable fuels facility to average 2,500 barrels per day for the first quarter of 2017 and 2,600 barrels per day for the full year of 2017.

“Our retail results were negatively impacted by seasonal weakness and continued economic headwinds in the Permian Basin. That said, we are encouraged by the increase in rig activity in the Permian, and we believe our retail segment is well positioned to benefit as the West Texas economy improves.”

FOURTH QUARTER 2016

Special items increased net loss by $3.8 million for the fourth quarter of 2016 primarily as a result of employee retention expenses of $2.0 million, unrealized losses of $3.8 million associated with commodity swaps, losses of $0.7 million related to an asphalt inventory adjustment and $0.1 million associated with losses recognized on disposition of assets, before income tax and non-controlling interest impacts of $2.8 million. Special items reduced net income by $37.9 million for the fourth quarter of 2015 primarily as a result of a loss on impairment of goodwill of $39.0 million, losses of $1.7 million related to an asphalt inventory adjustment, employee retention expenses of $1.3 million and unrealized losses of $1.1 million associated with commodity swaps, partially offset by insurance recoveries net of professional fees of $3.6 million and $1.3 million associated with gains recognized on disposition of assets, before income tax and non-controlling interest impacts of $0.2 million.

The combined total refinery average throughput for the fourth quarter of 2016 was 146,725 barrels per day (“bpd”), compared to a combined total refinery average throughput of 116,995 bpd for the fourth quarter of 2015. The Big Spring refinery average throughput for the fourth quarter of 2016 was 76,654 bpd, compared to 75,925 bpd for the fourth quarter of 2015. The Krotz Springs refinery average throughput for the fourth quarter of 2016 was 70,071 bpd, compared to 41,070 bpd for the fourth quarter of 2015. During the fourth quarter of 2016, the Krotz Springs refinery throughput was impacted by our election to reduce the crude rate in order to optimize the refinery yield. During the fourth quarter of 2015, throughput at our Krotz Springs refinery was lower as a result of downtime necessary to complete the planned major turnaround.

Refinery operating margin at the Big Spring refinery was $7.65 per barrel for the fourth quarter of 2016 compared to $10.02 per barrel for the same period in 2015. This decrease in operating margin was primarily due to increased RINs costs, a reduced benefit from the contango market environment which increased the cost of crude and unfavorable differences in Group III to Gulf Coast gasoline and diesel prices in the fourth quarter of 2016 compared to the same period in 2015.

Refinery operating margin at the Krotz Springs refinery was $3.40 per barrel for the fourth quarter of 2016 compared to $1.55 per barrel for the same period in 2015. During the fourth quarter of 2016, the Krotz Springs operating margin was favorably impacted by a higher Gulf Coast 2/1/1 high sulfur diesel crack spread and a widening of the WTI Cushing to WTI Midland spread, partially offset by a narrowing of the LLS to WTI Cushing spread, increased RINs costs and a reduced benefit from the contango market environment which increased the cost of crude. During the fourth quarter of 2015, the Krotz Springs operating margin reflects the negative impact of the planned major turnaround on refinery production.

The average Gulf Coast 3/2/1 crack spread was $12.83 per barrel for the fourth quarter of 2016 compared to $10.90 per barrel for the fourth quarter of 2015. The average Gulf Coast 2/1/1 high sulfur diesel crack spread was $8.63 per barrel for the fourth quarter of 2016 compared to $7.13 per barrel for the fourth quarter of 2015.

The average WTI Cushing to WTI Midland spread for the fourth quarter of 2016 was $0.25 per barrel compared to $(0.20) per barrel for the same period in 2015. The average WTI Cushing to WTS spread for the fourth quarter of 2016 was $1.33 per barrel compared to $(0.26) per barrel for the same period in 2015. The average LLS to WTI Cushing spread for the fourth quarter of 2016 was $1.42 per barrel compared to $2.08 per barrel for the same period in 2015. The average Brent to WTI Cushing spread for the fourth quarter of 2016 was $(0.20) per barrel compared to $1.35 per barrel for the same period in 2015. The average Brent to LLS spread for the fourth quarter of 2016 was $(1.36) per barrel compared to $(0.30) per barrel for the same period in 2015.

The average RINs cost effect on the Big Spring refinery operating margin was $1.08 per barrel for the fourth quarter of 2016, compared to $0.45 per barrel for the fourth quarter of 2015. The average RINs cost effect on the Krotz Springs refinery operating margin was $1.58 per barrel for the fourth quarter of 2016, compared to $0.60 per barrel for the fourth quarter of 2015.

The contango environment in the fourth quarter of 2016 created an average cost of crude benefit of $0.79 per barrel compared to an average cost of crude benefit of $0.94 per barrel for the same period in 2015.

For the fourth quarter of 2016, our California renewable fuels facility generated an operating margin of $70.57 per barrel from an average of 2,409 barrels per day of throughput. Our statements of operations include operating income of $8.7 million for the fourth quarter of 2016 related to the facility’s operations.

Asphalt margins for the fourth quarter of 2016 were $107.89 per ton compared to $102.85 per ton for the fourth quarter of 2015. On a cash basis (i.e. excluding inventory effects), asphalt margins in the fourth quarter of 2016 were $116.06 per ton compared to $106.92 per ton in the fourth quarter of 2015.

Retail fuel margins decreased to 18.5 cents per gallon in the fourth quarter of 2016 from 20.0 cents per gallon in the fourth quarter of 2015. Retail fuel sales volume increased to 54.0 million gallons in the fourth quarter of 2016 from 52.2 million gallons in the fourth quarter of 2015. Merchandise margins decreased to 30.5% in the fourth quarter of 2016 from 31.1% in the fourth quarter of 2015. Merchandise sales decreased to $78.9 million in the fourth quarter of 2016 from $81.0 million in the fourth quarter of 2015.

FULL-YEAR 2016

Special items increased net loss by $17.7 million for 2016 primarily as a result of employee retention expenses of $10.7 million, losses of $1.0 million related to an asphalt inventory adjustment, unrealized losses of $14.8 million associated with commodity swaps and $1.7 million associated with losses recognized on disposition of assets, before income tax and non-controlling interest impacts of $10.5 million. Special items reduced net income by $42.7 million for 2015 primarily as a result of a loss on impairment of goodwill of $39.0 million, losses of $8.1 million related to an asphalt inventory adjustment and employee retention expenses of $11.3 million, partially offset by unrealized gains of $7.9 million associated with commodity swaps, insurance recoveries net of professional fees of $3.6 million and $1.9 million associated with gains recognized on disposition of assets, before income tax and non-controlling interest impacts of $2.3 million.

Combined refinery average throughput for 2016 was 139,243 bpd, compared to a combined refinery average throughput of 140,036 bpd in 2015. The Big Spring refinery average throughput for 2016 was 71,363 bpd compared to 74,906 bpd for 2015. The reduced throughput at our Big Spring refinery during 2016 was the result of a reformer regeneration during the first quarter of 2016 and third quarter of 2016. Additionally, throughput was reduced as a result of a catalyst replacement for our diesel hydrotreater unit in the first quarter of 2016 and unplanned downtime during the second quarter of 2016 due to a power outage caused by inclement weather, which affected multiple units. The Krotz Springs refinery average throughput for 2016 was 67,880 bpd compared to 65,130 bpd for 2015. During 2016, the Krotz Springs refinery throughput was impacted by our election to reduce the crude rate in order to optimize the refinery yield, as well as maintenance that was performed on the fluid catalytic cracking unit during the second quarter of 2016. During 2015, we completed the planned major turnaround at the Krotz Springs refinery, which reduced throughput during the period.

Refinery operating margin at the Big Spring refinery was $8.28 per barrel for 2016 compared to $14.43 per barrel for 2015. This decrease in operating margin was primarily due to a lower Gulf Coast 3/2/1 crack spread, a narrowing of the WTI Cushing to WTI Midland spread and increased RINs costs, partially offset by a widening of the WTI Cushing to WTS spread and an increased benefit from the contango market environment which reduced the cost of crude.

Refinery operating margin at the Krotz Springs refinery was $3.06 per barrel for 2016 compared to $7.02 per barrel for 2015. This decrease in operating margin was primarily due to a lower Gulf Coast 2/1/1 high sulfur diesel crack spread, a narrowing of both the WTI Cushing to WTI Midland and the LLS to WTI Cushing spreads and increased RINs costs, partially offset by an increased benefit from the contango market environment which reduced the cost of crude.

The average Gulf Coast 3/2/1 crack spread for 2016 was $12.64 per barrel compared to $17.02 per barrel for 2015. The average Gulf Coast 2/1/1 high sulfur diesel crack spread for 2016 was $7.95 per barrel compared to $10.81 per barrel for 2015.

The average WTI Cushing to WTI Midland spread for 2016 was $0.15 per barrel compared to $0.39 per barrel for 2015. The average WTI Cushing to WTS spread for 2016 was $0.73 per barrel compared to $(0.06) per barrel for 2015. The average LLS to WTI Cushing spread for 2016 was $1.70 per barrel compared to $3.73 per barrel for 2015. The average Brent to WTI Cushing spread for 2016 was $0.21 per barrel compared to $3.54 per barrel for 2015. The average Brent to LLS spread for 2016 was $(1.45) per barrel compared to $0.14 per barrel for 2015.

The average RINs cost effect on the Big Spring refinery operating margin was $0.55 per barrel for 2016, compared to $0.42 per barrel for 2015. The average RINs cost effect on the Krotz Springs refinery operating margin was $1.48 per barrel for 2016, compared to $0.99 per barrel for 2015.

The contango environment in 2016 created an average cost of crude benefit of $1.24 per barrel compared to an average cost of crude benefit of $1.01 per barrel in 2015.

During 2016, our California renewable fuels facility generated an operating margin of $68.67 per barrel from an average of 2,275 barrels per day of throughput. Our statements of operations include operating income of $24.1 million in 2016 related to the facility’s operations.

Asphalt margins for 2016 were $98.80 per ton compared to $105.70 per ton in 2015. On a cash basis (i.e. excluding inventory effects), asphalt margins in 2016 were $100.94 per ton compared to $109.35 per ton in 2015.

Retail fuel margins decreased to 19.8 cents per gallon in 2016 from 21.3 cents per gallon in 2015. Retail fuel sales volume increased to 209.0 million gallons in 2016 from 199.1 million gallons in 2015. Merchandise margins decreased to 31.2% in 2016 from 31.9% in 2015. Merchandise sales decreased to $324.4 million in 2016 from $328.5 million in 2015.

Alon also announced today that its Board of Directors has declared the regular quarterly cash dividend of $0.15 per share. The dividend is payable on March 17, 2017 to stockholders of record at the close of business on March 9, 2017.

CONFERENCE CALL

Alon has scheduled a conference call, which will be broadcast live over the Internet on Friday, February 24, 2017, at 11:30 a.m. Eastern Time (10:30 a.m. Central Time), to discuss the fourth quarter and year-end 2016 financial results. To access the call, please dial 877-407-0672, or 412-902-0003 for international callers, and ask for the Alon USA Energy call at least 10 minutes prior to the start time. Investors may also listen to the conference live by logging on to the Alon investor relations website, http://ir.alonusa.com. A telephonic replay of the conference call will be available through March 3, 2017, and may be accessed by calling 877-660-6853, or 201-612-7415 for international callers, and using the passcode 13652999#. A webcast archive will also be available at http://ir.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. Alon owns 100% of the general partner and 81.6% of the limited partner interests in Alon USA Partners, LP (NYSE: ALDW), which owns a crude oil refinery in Big Spring, Texas, with a crude oil throughput capacity of 73,000 barrels per day and an integrated wholesale marketing business. In addition, Alon directly owns a crude oil refinery in Krotz Springs, Louisiana, with a crude oil throughput capacity of 74,000 barrels per day. Alon also owns crude oil refineries in California, which have not processed crude oil since 2012. Alon owns a majority interest in a renewable fuels facility in California, with a throughput capacity of 3,000 barrels per day. Alon is a leading marketer of asphalt, which it distributes primarily through asphalt terminals located predominately in the Southwestern and Western United States. Alon is the largest 7-Eleven licensee in the United States and operates approximately 300 convenience stores which also market motor fuels in Central and West 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.

 

SOURCE Alon USA Energy, Inc.

Alon USA Energy Reports Fourth Quarter and Full Year 2016 Results

DALLAS, Feb. 23, 2017 /PRNewswire/ — Alon USA Energy, Inc. (NYSE: ALJ) (“Alon”) today announced results for the fourth quarter and year ended December 31, 2016. Net loss available to stockholders for the fourth quarter of 2016 was $(18.1) million, or $(0.25) per share, compared to net loss available to stockholders of $(52.5) million, or $(0.75) per share, for the same period last year. Excluding special items, Alon recorded net loss available to stockholders of $(14.3) million, or $(0.20) per share, for the fourth quarter of 2016, compared to net loss available to stockholders of $(14.6) million, or $(0.21) per share, for the same period last year.

Net loss available to stockholders for the full year 2016 was $(82.8) million, or $(1.17) per share, compared to net income available to stockholders of $52.8 million, or $0.76 per share, for 2015. Excluding special items, Alon recorded net loss available to stockholders of $(65.1) million, or $(0.92) per share, for the full year 2016, compared to net income available to stockholders of $95.5 million, or $1.37 per share, for 2015.

As previously announced, in January 2017, Delek US and Alon entered into a definitive agreement under which Delek will acquire the outstanding shares of Alon common stock that Delek does not already own in an all-stock transaction. The transaction is expected to close in the first half of 2017, subject to customary closing conditions, including regulatory approval and approval by Delek US shareholders and Alon shareholders. We believe the economies of scale, financial strength and synergies generated through this merger create the opportunity to drive long-term value for shareholders.

In February 2017, the Krotz Springs refinery received approval from the EPA for a small refinery exemption from the requirements of the renewable fuel standard for the 2016 calendar year. As a result, we expect to book a reduction in RINs expense of $29.0 million in the first quarter of 2017, based on a weighted average RINs price per gallon of $0.58.

Alan Moret, CEO, commented, “Our diversification proved to be an asset for us in 2016, as positive contributions from our asphalt segment, retail segment and our renewable fuels facility in California helped offset the impact of weak crack spreads, high RIN prices and narrower crude differentials on our refining results. Our asphalt business operating income more than doubled in 2016 relative to 2015, as sales volumes increased by 19 percent and direct operating expenses were reduced by 8 percent. Our renewable fuels facility, which began operations in February 2016, produced approximately 30 million gallons of renewable fuel in 2016. We have been encouraged by the improvement in refining fundamentals that we saw at the end of 2016 and into 2017, including the widening of domestic crude discounts relative to Brent. We also are pleased to see RIN prices decline.

“The Big Spring refinery ran well in the fourth quarter, achieving total throughput of almost 77,000 barrels per day. The refinery also set a new quarterly record by processing over 44,000 barrels per day of WTI Midland in the quarter, further demonstrating the flexibility of the asset. The fourth quarter refinery operating margin of $7.65 per barrel is net of a negative impact of approximately $1.10 per barrel related to RINs costs. Operating expense in the quarter was low at $3.39 per barrel. As we’ve said before, we do not expect any major maintenance at Big Spring in 2017. We expect total throughput at the Big Spring refinery to average 77,000 barrels per day for the first quarter of 2017 and 75,000 barrels per day for the full year of 2017.

“The Krotz Springs refinery also ran well in the fourth quarter with total throughput of 70,000 barrels per day. The refinery operating margin of $3.40 per barrel was negatively impacted by approximately $1.60 per barrel due to the high cost of RINs. Operating expense in the fourth quarter was low at $3.44 per barrel. We expect total throughput at the Krotz Springs refinery to average 77,000 barrels per day for the first quarter of 2017 and 74,000 barrels per day for the full year of 2017.

“Our asphalt business performed exceptionally well in what is typically a seasonally weak quarter. Asphalt operating income of $3.2 million in the fourth quarter was driven by sales volumes of 133 thousand tons and an attractive margin of $108 per ton.

“Our renewable fuels facility in California had its most profitable quarter since operations began, generating $9 million of operating income in the fourth quarter. This was achieved in spite of reduced throughput of 2,400 barrels per day due to maintenance being done by a third-party supplier in the quarter. We expect total throughput at our renewable fuels facility to average 2,500 barrels per day for the first quarter of 2017 and 2,600 barrels per day for the full year of 2017.

“Our retail results were negatively impacted by seasonal weakness and continued economic headwinds in the Permian Basin. That said, we are encouraged by the increase in rig activity in the Permian, and we believe our retail segment is well positioned to benefit as the West Texas economy improves.”

FOURTH QUARTER 2016

Special items increased net loss by $3.8 million for the fourth quarter of 2016 primarily as a result of employee retention expenses of $2.0 million, unrealized losses of $3.8 million associated with commodity swaps, losses of $0.7 million related to an asphalt inventory adjustment and $0.1 million associated with losses recognized on disposition of assets, before income tax and non-controlling interest impacts of $2.8 million. Special items reduced net income by $37.9 million for the fourth quarter of 2015 primarily as a result of a loss on impairment of goodwill of $39.0 million, losses of $1.7 million related to an asphalt inventory adjustment, employee retention expenses of $1.3 million and unrealized losses of $1.1 million associated with commodity swaps, partially offset by insurance recoveries net of professional fees of $3.6 million and $1.3 million associated with gains recognized on disposition of assets, before income tax and non-controlling interest impacts of $0.2 million.

The combined total refinery average throughput for the fourth quarter of 2016 was 146,725 barrels per day (“bpd”), compared to a combined total refinery average throughput of 116,995 bpd for the fourth quarter of 2015. The Big Spring refinery average throughput for the fourth quarter of 2016 was 76,654 bpd, compared to 75,925 bpd for the fourth quarter of 2015. The Krotz Springs refinery average throughput for the fourth quarter of 2016 was 70,071 bpd, compared to 41,070 bpd for the fourth quarter of 2015. During the fourth quarter of 2016, the Krotz Springs refinery throughput was impacted by our election to reduce the crude rate in order to optimize the refinery yield. During the fourth quarter of 2015, throughput at our Krotz Springs refinery was lower as a result of downtime necessary to complete the planned major turnaround.

Refinery operating margin at the Big Spring refinery was $7.65 per barrel for the fourth quarter of 2016 compared to $10.02 per barrel for the same period in 2015. This decrease in operating margin was primarily due to increased RINs costs, a reduced benefit from the contango market environment which increased the cost of crude and unfavorable differences in Group III to Gulf Coast gasoline and diesel prices in the fourth quarter of 2016 compared to the same period in 2015.

Refinery operating margin at the Krotz Springs refinery was $3.40 per barrel for the fourth quarter of 2016 compared to $1.55 per barrel for the same period in 2015. During the fourth quarter of 2016, the Krotz Springs operating margin was favorably impacted by a higher Gulf Coast 2/1/1 high sulfur diesel crack spread and a widening of the WTI Cushing to WTI Midland spread, partially offset by a narrowing of the LLS to WTI Cushing spread, increased RINs costs and a reduced benefit from the contango market environment which increased the cost of crude. During the fourth quarter of 2015, the Krotz Springs operating margin reflects the negative impact of the planned major turnaround on refinery production.

The average Gulf Coast 3/2/1 crack spread was $12.83 per barrel for the fourth quarter of 2016 compared to $10.90 per barrel for the fourth quarter of 2015. The average Gulf Coast 2/1/1 high sulfur diesel crack spread was $8.63 per barrel for the fourth quarter of 2016 compared to $7.13 per barrel for the fourth quarter of 2015.

The average WTI Cushing to WTI Midland spread for the fourth quarter of 2016 was $0.25 per barrel compared to $(0.20) per barrel for the same period in 2015. The average WTI Cushing to WTS spread for the fourth quarter of 2016 was $1.33 per barrel compared to $(0.26) per barrel for the same period in 2015. The average LLS to WTI Cushing spread for the fourth quarter of 2016 was $1.42 per barrel compared to $2.08 per barrel for the same period in 2015. The average Brent to WTI Cushing spread for the fourth quarter of 2016 was $(0.20) per barrel compared to $1.35 per barrel for the same period in 2015. The average Brent to LLS spread for the fourth quarter of 2016 was $(1.36) per barrel compared to $(0.30) per barrel for the same period in 2015.

The average RINs cost effect on the Big Spring refinery operating margin was $1.08 per barrel for the fourth quarter of 2016, compared to $0.45 per barrel for the fourth quarter of 2015. The average RINs cost effect on the Krotz Springs refinery operating margin was $1.58 per barrel for the fourth quarter of 2016, compared to $0.60 per barrel for the fourth quarter of 2015.

The contango environment in the fourth quarter of 2016 created an average cost of crude benefit of $0.79 per barrel compared to an average cost of crude benefit of $0.94 per barrel for the same period in 2015.

For the fourth quarter of 2016, our California renewable fuels facility generated an operating margin of $70.57 per barrel from an average of 2,409 barrels per day of throughput. Our statements of operations include operating income of $8.7 million for the fourth quarter of 2016 related to the facility’s operations.

Asphalt margins for the fourth quarter of 2016 were $107.89 per ton compared to $102.85 per ton for the fourth quarter of 2015. On a cash basis (i.e. excluding inventory effects), asphalt margins in the fourth quarter of 2016 were $116.06 per ton compared to $106.92 per ton in the fourth quarter of 2015.

Retail fuel margins decreased to 18.5 cents per gallon in the fourth quarter of 2016 from 20.0 cents per gallon in the fourth quarter of 2015. Retail fuel sales volume increased to 54.0 million gallons in the fourth quarter of 2016 from 52.2 million gallons in the fourth quarter of 2015. Merchandise margins decreased to 30.5% in the fourth quarter of 2016 from 31.1% in the fourth quarter of 2015. Merchandise sales decreased to $78.9 million in the fourth quarter of 2016 from $81.0 million in the fourth quarter of 2015.

FULL-YEAR 2016

Special items increased net loss by $17.7 million for 2016 primarily as a result of employee retention expenses of $10.7 million, losses of $1.0 million related to an asphalt inventory adjustment, unrealized losses of $14.8 million associated with commodity swaps and $1.7 million associated with losses recognized on disposition of assets, before income tax and non-controlling interest impacts of $10.5 million. Special items reduced net income by $42.7 million for 2015 primarily as a result of a loss on impairment of goodwill of $39.0 million, losses of $8.1 million related to an asphalt inventory adjustment and employee retention expenses of $11.3 million, partially offset by unrealized gains of $7.9 million associated with commodity swaps, insurance recoveries net of professional fees of $3.6 million and $1.9 million associated with gains recognized on disposition of assets, before income tax and non-controlling interest impacts of $2.3 million.

Combined refinery average throughput for 2016 was 139,243 bpd, compared to a combined refinery average throughput of 140,036 bpd in 2015. The Big Spring refinery average throughput for 2016 was 71,363 bpd compared to 74,906 bpd for 2015. The reduced throughput at our Big Spring refinery during 2016 was the result of a reformer regeneration during the first quarter of 2016 and third quarter of 2016. Additionally, throughput was reduced as a result of a catalyst replacement for our diesel hydrotreater unit in the first quarter of 2016 and unplanned downtime during the second quarter of 2016 due to a power outage caused by inclement weather, which affected multiple units. The Krotz Springs refinery average throughput for 2016 was 67,880 bpd compared to 65,130 bpd for 2015. During 2016, the Krotz Springs refinery throughput was impacted by our election to reduce the crude rate in order to optimize the refinery yield, as well as maintenance that was performed on the fluid catalytic cracking unit during the second quarter of 2016. During 2015, we completed the planned major turnaround at the Krotz Springs refinery, which reduced throughput during the period.

Refinery operating margin at the Big Spring refinery was $8.28 per barrel for 2016 compared to $14.43 per barrel for 2015. This decrease in operating margin was primarily due to a lower Gulf Coast 3/2/1 crack spread, a narrowing of the WTI Cushing to WTI Midland spread and increased RINs costs, partially offset by a widening of the WTI Cushing to WTS spread and an increased benefit from the contango market environment which reduced the cost of crude.

Refinery operating margin at the Krotz Springs refinery was $3.06 per barrel for 2016 compared to $7.02 per barrel for 2015. This decrease in operating margin was primarily due to a lower Gulf Coast 2/1/1 high sulfur diesel crack spread, a narrowing of both the WTI Cushing to WTI Midland and the LLS to WTI Cushing spreads and increased RINs costs, partially offset by an increased benefit from the contango market environment which reduced the cost of crude.

The average Gulf Coast 3/2/1 crack spread for 2016 was $12.64 per barrel compared to $17.02 per barrel for 2015. The average Gulf Coast 2/1/1 high sulfur diesel crack spread for 2016 was $7.95 per barrel compared to $10.81 per barrel for 2015.

The average WTI Cushing to WTI Midland spread for 2016 was $0.15 per barrel compared to $0.39 per barrel for 2015. The average WTI Cushing to WTS spread for 2016 was $0.73 per barrel compared to $(0.06) per barrel for 2015. The average LLS to WTI Cushing spread for 2016 was $1.70 per barrel compared to $3.73 per barrel for 2015. The average Brent to WTI Cushing spread for 2016 was $0.21 per barrel compared to $3.54 per barrel for 2015. The average Brent to LLS spread for 2016 was $(1.45) per barrel compared to $0.14 per barrel for 2015.

The average RINs cost effect on the Big Spring refinery operating margin was $0.55 per barrel for 2016, compared to $0.42 per barrel for 2015. The average RINs cost effect on the Krotz Springs refinery operating margin was $1.48 per barrel for 2016, compared to $0.99 per barrel for 2015.

The contango environment in 2016 created an average cost of crude benefit of $1.24 per barrel compared to an average cost of crude benefit of $1.01 per barrel in 2015.

During 2016, our California renewable fuels facility generated an operating margin of $68.67 per barrel from an average of 2,275 barrels per day of throughput. Our statements of operations include operating income of $24.1 million in 2016 related to the facility’s operations.

Asphalt margins for 2016 were $98.80 per ton compared to $105.70 per ton in 2015. On a cash basis (i.e. excluding inventory effects), asphalt margins in 2016 were $100.94 per ton compared to $109.35 per ton in 2015.

Retail fuel margins decreased to 19.8 cents per gallon in 2016 from 21.3 cents per gallon in 2015. Retail fuel sales volume increased to 209.0 million gallons in 2016 from 199.1 million gallons in 2015. Merchandise margins decreased to 31.2% in 2016 from 31.9% in 2015. Merchandise sales decreased to $324.4 million in 2016 from $328.5 million in 2015.

Alon also announced today that its Board of Directors has declared the regular quarterly cash dividend of $0.15 per share. The dividend is payable on March 17, 2017 to stockholders of record at the close of business on March 9, 2017.

CONFERENCE CALL

Alon has scheduled a conference call, which will be broadcast live over the Internet on Friday, February 24, 2017, at 11:30 a.m. Eastern Time (10:30 a.m. Central Time), to discuss the fourth quarter and year-end 2016 financial results. To access the call, please dial 877-407-0672, or 412-902-0003 for international callers, and ask for the Alon USA Energy call at least 10 minutes prior to the start time. Investors may also listen to the conference live by logging on to the Alon investor relations website, http://ir.alonusa.com. A telephonic replay of the conference call will be available through March 3, 2017, and may be accessed by calling 877-660-6853, or 201-612-7415 for international callers, and using the passcode 13652999#. A webcast archive will also be available at http://ir.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. Alon owns 100% of the general partner and 81.6% of the limited partner interests in Alon USA Partners, LP (NYSE: ALDW), which owns a crude oil refinery in Big Spring, Texas, with a crude oil throughput capacity of 73,000 barrels per day and an integrated wholesale marketing business. In addition, Alon directly owns a crude oil refinery in Krotz Springs, Louisiana, with a crude oil throughput capacity of 74,000 barrels per day. Alon also owns crude oil refineries in California, which have not processed crude oil since 2012. Alon owns a majority interest in a renewable fuels facility in California, with a throughput capacity of 3,000 barrels per day. Alon is a leading marketer of asphalt, which it distributes primarily through asphalt terminals located predominately in the Southwestern and Western United States. Alon is the largest 7-Eleven licensee in the United States and operates approximately 300 convenience stores which also market motor fuels in Central and West 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.

 

SOURCE Alon USA Energy, Inc.

Alon USA Energy Reports Fourth Quarter and Full Year 2016 Results

DALLAS, Feb. 23, 2017 /PRNewswire/ — Alon USA Energy, Inc. (NYSE: ALJ) (“Alon”) today announced results for the fourth quarter and year ended December 31, 2016. Net loss available to stockholders for the fourth quarter of 2016 was $(18.1) million, or $(0.25) per share, compared to net loss available to stockholders of $(52.5) million, or $(0.75) per share, for the same period last year. Excluding special items, Alon recorded net loss available to stockholders of $(14.3) million, or $(0.20) per share, for the fourth quarter of 2016, compared to net loss available to stockholders of $(14.6) million, or $(0.21) per share, for the same period last year.

Net loss available to stockholders for the full year 2016 was $(82.8) million, or $(1.17) per share, compared to net income available to stockholders of $52.8 million, or $0.76 per share, for 2015. Excluding special items, Alon recorded net loss available to stockholders of $(65.1) million, or $(0.92) per share, for the full year 2016, compared to net income available to stockholders of $95.5 million, or $1.37 per share, for 2015.

As previously announced, in January 2017, Delek US and Alon entered into a definitive agreement under which Delek will acquire the outstanding shares of Alon common stock that Delek does not already own in an all-stock transaction. The transaction is expected to close in the first half of 2017, subject to customary closing conditions, including regulatory approval and approval by Delek US shareholders and Alon shareholders. We believe the economies of scale, financial strength and synergies generated through this merger create the opportunity to drive long-term value for shareholders.

In February 2017, the Krotz Springs refinery received approval from the EPA for a small refinery exemption from the requirements of the renewable fuel standard for the 2016 calendar year. As a result, we expect to book a reduction in RINs expense of $29.0 million in the first quarter of 2017, based on a weighted average RINs price per gallon of $0.58.

Alan Moret, CEO, commented, “Our diversification proved to be an asset for us in 2016, as positive contributions from our asphalt segment, retail segment and our renewable fuels facility in California helped offset the impact of weak crack spreads, high RIN prices and narrower crude differentials on our refining results. Our asphalt business operating income more than doubled in 2016 relative to 2015, as sales volumes increased by 19 percent and direct operating expenses were reduced by 8 percent. Our renewable fuels facility, which began operations in February 2016, produced approximately 30 million gallons of renewable fuel in 2016. We have been encouraged by the improvement in refining fundamentals that we saw at the end of 2016 and into 2017, including the widening of domestic crude discounts relative to Brent. We also are pleased to see RIN prices decline.

“The Big Spring refinery ran well in the fourth quarter, achieving total throughput of almost 77,000 barrels per day. The refinery also set a new quarterly record by processing over 44,000 barrels per day of WTI Midland in the quarter, further demonstrating the flexibility of the asset. The fourth quarter refinery operating margin of $7.65 per barrel is net of a negative impact of approximately $1.10 per barrel related to RINs costs. Operating expense in the quarter was low at $3.39 per barrel. As we’ve said before, we do not expect any major maintenance at Big Spring in 2017. We expect total throughput at the Big Spring refinery to average 77,000 barrels per day for the first quarter of 2017 and 75,000 barrels per day for the full year of 2017.

“The Krotz Springs refinery also ran well in the fourth quarter with total throughput of 70,000 barrels per day. The refinery operating margin of $3.40 per barrel was negatively impacted by approximately $1.60 per barrel due to the high cost of RINs. Operating expense in the fourth quarter was low at $3.44 per barrel. We expect total throughput at the Krotz Springs refinery to average 77,000 barrels per day for the first quarter of 2017 and 74,000 barrels per day for the full year of 2017.

“Our asphalt business performed exceptionally well in what is typically a seasonally weak quarter. Asphalt operating income of $3.2 million in the fourth quarter was driven by sales volumes of 133 thousand tons and an attractive margin of $108 per ton.

“Our renewable fuels facility in California had its most profitable quarter since operations began, generating $9 million of operating income in the fourth quarter. This was achieved in spite of reduced throughput of 2,400 barrels per day due to maintenance being done by a third-party supplier in the quarter. We expect total throughput at our renewable fuels facility to average 2,500 barrels per day for the first quarter of 2017 and 2,600 barrels per day for the full year of 2017.

“Our retail results were negatively impacted by seasonal weakness and continued economic headwinds in the Permian Basin. That said, we are encouraged by the increase in rig activity in the Permian, and we believe our retail segment is well positioned to benefit as the West Texas economy improves.”

FOURTH QUARTER 2016

Special items increased net loss by $3.8 million for the fourth quarter of 2016 primarily as a result of employee retention expenses of $2.0 million, unrealized losses of $3.8 million associated with commodity swaps, losses of $0.7 million related to an asphalt inventory adjustment and $0.1 million associated with losses recognized on disposition of assets, before income tax and non-controlling interest impacts of $2.8 million. Special items reduced net income by $37.9 million for the fourth quarter of 2015 primarily as a result of a loss on impairment of goodwill of $39.0 million, losses of $1.7 million related to an asphalt inventory adjustment, employee retention expenses of $1.3 million and unrealized losses of $1.1 million associated with commodity swaps, partially offset by insurance recoveries net of professional fees of $3.6 million and $1.3 million associated with gains recognized on disposition of assets, before income tax and non-controlling interest impacts of $0.2 million.

The combined total refinery average throughput for the fourth quarter of 2016 was 146,725 barrels per day (“bpd”), compared to a combined total refinery average throughput of 116,995 bpd for the fourth quarter of 2015. The Big Spring refinery average throughput for the fourth quarter of 2016 was 76,654 bpd, compared to 75,925 bpd for the fourth quarter of 2015. The Krotz Springs refinery average throughput for the fourth quarter of 2016 was 70,071 bpd, compared to 41,070 bpd for the fourth quarter of 2015. During the fourth quarter of 2016, the Krotz Springs refinery throughput was impacted by our election to reduce the crude rate in order to optimize the refinery yield. During the fourth quarter of 2015, throughput at our Krotz Springs refinery was lower as a result of downtime necessary to complete the planned major turnaround.

Refinery operating margin at the Big Spring refinery was $7.65 per barrel for the fourth quarter of 2016 compared to $10.02 per barrel for the same period in 2015. This decrease in operating margin was primarily due to increased RINs costs, a reduced benefit from the contango market environment which increased the cost of crude and unfavorable differences in Group III to Gulf Coast gasoline and diesel prices in the fourth quarter of 2016 compared to the same period in 2015.

Refinery operating margin at the Krotz Springs refinery was $3.40 per barrel for the fourth quarter of 2016 compared to $1.55 per barrel for the same period in 2015. During the fourth quarter of 2016, the Krotz Springs operating margin was favorably impacted by a higher Gulf Coast 2/1/1 high sulfur diesel crack spread and a widening of the WTI Cushing to WTI Midland spread, partially offset by a narrowing of the LLS to WTI Cushing spread, increased RINs costs and a reduced benefit from the contango market environment which increased the cost of crude. During the fourth quarter of 2015, the Krotz Springs operating margin reflects the negative impact of the planned major turnaround on refinery production.

The average Gulf Coast 3/2/1 crack spread was $12.83 per barrel for the fourth quarter of 2016 compared to $10.90 per barrel for the fourth quarter of 2015. The average Gulf Coast 2/1/1 high sulfur diesel crack spread was $8.63 per barrel for the fourth quarter of 2016 compared to $7.13 per barrel for the fourth quarter of 2015.

The average WTI Cushing to WTI Midland spread for the fourth quarter of 2016 was $0.25 per barrel compared to $(0.20) per barrel for the same period in 2015. The average WTI Cushing to WTS spread for the fourth quarter of 2016 was $1.33 per barrel compared to $(0.26) per barrel for the same period in 2015. The average LLS to WTI Cushing spread for the fourth quarter of 2016 was $1.42 per barrel compared to $2.08 per barrel for the same period in 2015. The average Brent to WTI Cushing spread for the fourth quarter of 2016 was $(0.20) per barrel compared to $1.35 per barrel for the same period in 2015. The average Brent to LLS spread for the fourth quarter of 2016 was $(1.36) per barrel compared to $(0.30) per barrel for the same period in 2015.

The average RINs cost effect on the Big Spring refinery operating margin was $1.08 per barrel for the fourth quarter of 2016, compared to $0.45 per barrel for the fourth quarter of 2015. The average RINs cost effect on the Krotz Springs refinery operating margin was $1.58 per barrel for the fourth quarter of 2016, compared to $0.60 per barrel for the fourth quarter of 2015.

The contango environment in the fourth quarter of 2016 created an average cost of crude benefit of $0.79 per barrel compared to an average cost of crude benefit of $0.94 per barrel for the same period in 2015.

For the fourth quarter of 2016, our California renewable fuels facility generated an operating margin of $70.57 per barrel from an average of 2,409 barrels per day of throughput. Our statements of operations include operating income of $8.7 million for the fourth quarter of 2016 related to the facility’s operations.

Asphalt margins for the fourth quarter of 2016 were $107.89 per ton compared to $102.85 per ton for the fourth quarter of 2015. On a cash basis (i.e. excluding inventory effects), asphalt margins in the fourth quarter of 2016 were $116.06 per ton compared to $106.92 per ton in the fourth quarter of 2015.

Retail fuel margins decreased to 18.5 cents per gallon in the fourth quarter of 2016 from 20.0 cents per gallon in the fourth quarter of 2015. Retail fuel sales volume increased to 54.0 million gallons in the fourth quarter of 2016 from 52.2 million gallons in the fourth quarter of 2015. Merchandise margins decreased to 30.5% in the fourth quarter of 2016 from 31.1% in the fourth quarter of 2015. Merchandise sales decreased to $78.9 million in the fourth quarter of 2016 from $81.0 million in the fourth quarter of 2015.

FULL-YEAR 2016

Special items increased net loss by $17.7 million for 2016 primarily as a result of employee retention expenses of $10.7 million, losses of $1.0 million related to an asphalt inventory adjustment, unrealized losses of $14.8 million associated with commodity swaps and $1.7 million associated with losses recognized on disposition of assets, before income tax and non-controlling interest impacts of $10.5 million. Special items reduced net income by $42.7 million for 2015 primarily as a result of a loss on impairment of goodwill of $39.0 million, losses of $8.1 million related to an asphalt inventory adjustment and employee retention expenses of $11.3 million, partially offset by unrealized gains of $7.9 million associated with commodity swaps, insurance recoveries net of professional fees of $3.6 million and $1.9 million associated with gains recognized on disposition of assets, before income tax and non-controlling interest impacts of $2.3 million.

Combined refinery average throughput for 2016 was 139,243 bpd, compared to a combined refinery average throughput of 140,036 bpd in 2015. The Big Spring refinery average throughput for 2016 was 71,363 bpd compared to 74,906 bpd for 2015. The reduced throughput at our Big Spring refinery during 2016 was the result of a reformer regeneration during the first quarter of 2016 and third quarter of 2016. Additionally, throughput was reduced as a result of a catalyst replacement for our diesel hydrotreater unit in the first quarter of 2016 and unplanned downtime during the second quarter of 2016 due to a power outage caused by inclement weather, which affected multiple units. The Krotz Springs refinery average throughput for 2016 was 67,880 bpd compared to 65,130 bpd for 2015. During 2016, the Krotz Springs refinery throughput was impacted by our election to reduce the crude rate in order to optimize the refinery yield, as well as maintenance that was performed on the fluid catalytic cracking unit during the second quarter of 2016. During 2015, we completed the planned major turnaround at the Krotz Springs refinery, which reduced throughput during the period.

Refinery operating margin at the Big Spring refinery was $8.28 per barrel for 2016 compared to $14.43 per barrel for 2015. This decrease in operating margin was primarily due to a lower Gulf Coast 3/2/1 crack spread, a narrowing of the WTI Cushing to WTI Midland spread and increased RINs costs, partially offset by a widening of the WTI Cushing to WTS spread and an increased benefit from the contango market environment which reduced the cost of crude.

Refinery operating margin at the Krotz Springs refinery was $3.06 per barrel for 2016 compared to $7.02 per barrel for 2015. This decrease in operating margin was primarily due to a lower Gulf Coast 2/1/1 high sulfur diesel crack spread, a narrowing of both the WTI Cushing to WTI Midland and the LLS to WTI Cushing spreads and increased RINs costs, partially offset by an increased benefit from the contango market environment which reduced the cost of crude.

The average Gulf Coast 3/2/1 crack spread for 2016 was $12.64 per barrel compared to $17.02 per barrel for 2015. The average Gulf Coast 2/1/1 high sulfur diesel crack spread for 2016 was $7.95 per barrel compared to $10.81 per barrel for 2015.

The average WTI Cushing to WTI Midland spread for 2016 was $0.15 per barrel compared to $0.39 per barrel for 2015. The average WTI Cushing to WTS spread for 2016 was $0.73 per barrel compared to $(0.06) per barrel for 2015. The average LLS to WTI Cushing spread for 2016 was $1.70 per barrel compared to $3.73 per barrel for 2015. The average Brent to WTI Cushing spread for 2016 was $0.21 per barrel compared to $3.54 per barrel for 2015. The average Brent to LLS spread for 2016 was $(1.45) per barrel compared to $0.14 per barrel for 2015.

The average RINs cost effect on the Big Spring refinery operating margin was $0.55 per barrel for 2016, compared to $0.42 per barrel for 2015. The average RINs cost effect on the Krotz Springs refinery operating margin was $1.48 per barrel for 2016, compared to $0.99 per barrel for 2015.

The contango environment in 2016 created an average cost of crude benefit of $1.24 per barrel compared to an average cost of crude benefit of $1.01 per barrel in 2015.

During 2016, our California renewable fuels facility generated an operating margin of $68.67 per barrel from an average of 2,275 barrels per day of throughput. Our statements of operations include operating income of $24.1 million in 2016 related to the facility’s operations.

Asphalt margins for 2016 were $98.80 per ton compared to $105.70 per ton in 2015. On a cash basis (i.e. excluding inventory effects), asphalt margins in 2016 were $100.94 per ton compared to $109.35 per ton in 2015.

Retail fuel margins decreased to 19.8 cents per gallon in 2016 from 21.3 cents per gallon in 2015. Retail fuel sales volume increased to 209.0 million gallons in 2016 from 199.1 million gallons in 2015. Merchandise margins decreased to 31.2% in 2016 from 31.9% in 2015. Merchandise sales decreased to $324.4 million in 2016 from $328.5 million in 2015.

Alon also announced today that its Board of Directors has declared the regular quarterly cash dividend of $0.15 per share. The dividend is payable on March 17, 2017 to stockholders of record at the close of business on March 9, 2017.

CONFERENCE CALL

Alon has scheduled a conference call, which will be broadcast live over the Internet on Friday, February 24, 2017, at 11:30 a.m. Eastern Time (10:30 a.m. Central Time), to discuss the fourth quarter and year-end 2016 financial results. To access the call, please dial 877-407-0672, or 412-902-0003 for international callers, and ask for the Alon USA Energy call at least 10 minutes prior to the start time. Investors may also listen to the conference live by logging on to the Alon investor relations website, http://ir.alonusa.com. A telephonic replay of the conference call will be available through March 3, 2017, and may be accessed by calling 877-660-6853, or 201-612-7415 for international callers, and using the passcode 13652999#. A webcast archive will also be available at http://ir.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. Alon owns 100% of the general partner and 81.6% of the limited partner interests in Alon USA Partners, LP (NYSE: ALDW), which owns a crude oil refinery in Big Spring, Texas, with a crude oil throughput capacity of 73,000 barrels per day and an integrated wholesale marketing business. In addition, Alon directly owns a crude oil refinery in Krotz Springs, Louisiana, with a crude oil throughput capacity of 74,000 barrels per day. Alon also owns crude oil refineries in California, which have not processed crude oil since 2012. Alon owns a majority interest in a renewable fuels facility in California, with a throughput capacity of 3,000 barrels per day. Alon is a leading marketer of asphalt, which it distributes primarily through asphalt terminals located predominately in the Southwestern and Western United States. Alon is the largest 7-Eleven licensee in the United States and operates approximately 300 convenience stores which also market motor fuels in Central and West 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.

 

SOURCE Alon USA Energy, Inc.

Alon USA Energy Reports Fourth Quarter and Full Year 2016 Results

DALLAS, Feb. 23, 2017 /PRNewswire/ — Alon USA Energy, Inc. (NYSE: ALJ) (“Alon”) today announced results for the fourth quarter and year ended December 31, 2016. Net loss available to stockholders for the fourth quarter of 2016 was $(18.1) million, or $(0.25) per share, compared to net loss available to stockholders of $(52.5) million, or $(0.75) per share, for the same period last year. Excluding special items, Alon recorded net loss available to stockholders of $(14.3) million, or $(0.20) per share, for the fourth quarter of 2016, compared to net loss available to stockholders of $(14.6) million, or $(0.21) per share, for the same period last year.

Net loss available to stockholders for the full year 2016 was $(82.8) million, or $(1.17) per share, compared to net income available to stockholders of $52.8 million, or $0.76 per share, for 2015. Excluding special items, Alon recorded net loss available to stockholders of $(65.1) million, or $(0.92) per share, for the full year 2016, compared to net income available to stockholders of $95.5 million, or $1.37 per share, for 2015.

As previously announced, in January 2017, Delek US and Alon entered into a definitive agreement under which Delek will acquire the outstanding shares of Alon common stock that Delek does not already own in an all-stock transaction. The transaction is expected to close in the first half of 2017, subject to customary closing conditions, including regulatory approval and approval by Delek US shareholders and Alon shareholders. We believe the economies of scale, financial strength and synergies generated through this merger create the opportunity to drive long-term value for shareholders.

In February 2017, the Krotz Springs refinery received approval from the EPA for a small refinery exemption from the requirements of the renewable fuel standard for the 2016 calendar year. As a result, we expect to book a reduction in RINs expense of $29.0 million in the first quarter of 2017, based on a weighted average RINs price per gallon of $0.58.

Alan Moret, CEO, commented, “Our diversification proved to be an asset for us in 2016, as positive contributions from our asphalt segment, retail segment and our renewable fuels facility in California helped offset the impact of weak crack spreads, high RIN prices and narrower crude differentials on our refining results. Our asphalt business operating income more than doubled in 2016 relative to 2015, as sales volumes increased by 19 percent and direct operating expenses were reduced by 8 percent. Our renewable fuels facility, which began operations in February 2016, produced approximately 30 million gallons of renewable fuel in 2016. We have been encouraged by the improvement in refining fundamentals that we saw at the end of 2016 and into 2017, including the widening of domestic crude discounts relative to Brent. We also are pleased to see RIN prices decline.

“The Big Spring refinery ran well in the fourth quarter, achieving total throughput of almost 77,000 barrels per day. The refinery also set a new quarterly record by processing over 44,000 barrels per day of WTI Midland in the quarter, further demonstrating the flexibility of the asset. The fourth quarter refinery operating margin of $7.65 per barrel is net of a negative impact of approximately $1.10 per barrel related to RINs costs. Operating expense in the quarter was low at $3.39 per barrel. As we’ve said before, we do not expect any major maintenance at Big Spring in 2017. We expect total throughput at the Big Spring refinery to average 77,000 barrels per day for the first quarter of 2017 and 75,000 barrels per day for the full year of 2017.

“The Krotz Springs refinery also ran well in the fourth quarter with total throughput of 70,000 barrels per day. The refinery operating margin of $3.40 per barrel was negatively impacted by approximately $1.60 per barrel due to the high cost of RINs. Operating expense in the fourth quarter was low at $3.44 per barrel. We expect total throughput at the Krotz Springs refinery to average 77,000 barrels per day for the first quarter of 2017 and 74,000 barrels per day for the full year of 2017.

“Our asphalt business performed exceptionally well in what is typically a seasonally weak quarter. Asphalt operating income of $3.2 million in the fourth quarter was driven by sales volumes of 133 thousand tons and an attractive margin of $108 per ton.

“Our renewable fuels facility in California had its most profitable quarter since operations began, generating $9 million of operating income in the fourth quarter. This was achieved in spite of reduced throughput of 2,400 barrels per day due to maintenance being done by a third-party supplier in the quarter. We expect total throughput at our renewable fuels facility to average 2,500 barrels per day for the first quarter of 2017 and 2,600 barrels per day for the full year of 2017.

“Our retail results were negatively impacted by seasonal weakness and continued economic headwinds in the Permian Basin. That said, we are encouraged by the increase in rig activity in the Permian, and we believe our retail segment is well positioned to benefit as the West Texas economy improves.”

FOURTH QUARTER 2016

Special items increased net loss by $3.8 million for the fourth quarter of 2016 primarily as a result of employee retention expenses of $2.0 million, unrealized losses of $3.8 million associated with commodity swaps, losses of $0.7 million related to an asphalt inventory adjustment and $0.1 million associated with losses recognized on disposition of assets, before income tax and non-controlling interest impacts of $2.8 million. Special items reduced net income by $37.9 million for the fourth quarter of 2015 primarily as a result of a loss on impairment of goodwill of $39.0 million, losses of $1.7 million related to an asphalt inventory adjustment, employee retention expenses of $1.3 million and unrealized losses of $1.1 million associated with commodity swaps, partially offset by insurance recoveries net of professional fees of $3.6 million and $1.3 million associated with gains recognized on disposition of assets, before income tax and non-controlling interest impacts of $0.2 million.

The combined total refinery average throughput for the fourth quarter of 2016 was 146,725 barrels per day (“bpd”), compared to a combined total refinery average throughput of 116,995 bpd for the fourth quarter of 2015. The Big Spring refinery average throughput for the fourth quarter of 2016 was 76,654 bpd, compared to 75,925 bpd for the fourth quarter of 2015. The Krotz Springs refinery average throughput for the fourth quarter of 2016 was 70,071 bpd, compared to 41,070 bpd for the fourth quarter of 2015. During the fourth quarter of 2016, the Krotz Springs refinery throughput was impacted by our election to reduce the crude rate in order to optimize the refinery yield. During the fourth quarter of 2015, throughput at our Krotz Springs refinery was lower as a result of downtime necessary to complete the planned major turnaround.

Refinery operating margin at the Big Spring refinery was $7.65 per barrel for the fourth quarter of 2016 compared to $10.02 per barrel for the same period in 2015. This decrease in operating margin was primarily due to increased RINs costs, a reduced benefit from the contango market environment which increased the cost of crude and unfavorable differences in Group III to Gulf Coast gasoline and diesel prices in the fourth quarter of 2016 compared to the same period in 2015.

Refinery operating margin at the Krotz Springs refinery was $3.40 per barrel for the fourth quarter of 2016 compared to $1.55 per barrel for the same period in 2015. During the fourth quarter of 2016, the Krotz Springs operating margin was favorably impacted by a higher Gulf Coast 2/1/1 high sulfur diesel crack spread and a widening of the WTI Cushing to WTI Midland spread, partially offset by a narrowing of the LLS to WTI Cushing spread, increased RINs costs and a reduced benefit from the contango market environment which increased the cost of crude. During the fourth quarter of 2015, the Krotz Springs operating margin reflects the negative impact of the planned major turnaround on refinery production.

The average Gulf Coast 3/2/1 crack spread was $12.83 per barrel for the fourth quarter of 2016 compared to $10.90 per barrel for the fourth quarter of 2015. The average Gulf Coast 2/1/1 high sulfur diesel crack spread was $8.63 per barrel for the fourth quarter of 2016 compared to $7.13 per barrel for the fourth quarter of 2015.

The average WTI Cushing to WTI Midland spread for the fourth quarter of 2016 was $0.25 per barrel compared to $(0.20) per barrel for the same period in 2015. The average WTI Cushing to WTS spread for the fourth quarter of 2016 was $1.33 per barrel compared to $(0.26) per barrel for the same period in 2015. The average LLS to WTI Cushing spread for the fourth quarter of 2016 was $1.42 per barrel compared to $2.08 per barrel for the same period in 2015. The average Brent to WTI Cushing spread for the fourth quarter of 2016 was $(0.20) per barrel compared to $1.35 per barrel for the same period in 2015. The average Brent to LLS spread for the fourth quarter of 2016 was $(1.36) per barrel compared to $(0.30) per barrel for the same period in 2015.

The average RINs cost effect on the Big Spring refinery operating margin was $1.08 per barrel for the fourth quarter of 2016, compared to $0.45 per barrel for the fourth quarter of 2015. The average RINs cost effect on the Krotz Springs refinery operating margin was $1.58 per barrel for the fourth quarter of 2016, compared to $0.60 per barrel for the fourth quarter of 2015.

The contango environment in the fourth quarter of 2016 created an average cost of crude benefit of $0.79 per barrel compared to an average cost of crude benefit of $0.94 per barrel for the same period in 2015.

For the fourth quarter of 2016, our California renewable fuels facility generated an operating margin of $70.57 per barrel from an average of 2,409 barrels per day of throughput. Our statements of operations include operating income of $8.7 million for the fourth quarter of 2016 related to the facility’s operations.

Asphalt margins for the fourth quarter of 2016 were $107.89 per ton compared to $102.85 per ton for the fourth quarter of 2015. On a cash basis (i.e. excluding inventory effects), asphalt margins in the fourth quarter of 2016 were $116.06 per ton compared to $106.92 per ton in the fourth quarter of 2015.

Retail fuel margins decreased to 18.5 cents per gallon in the fourth quarter of 2016 from 20.0 cents per gallon in the fourth quarter of 2015. Retail fuel sales volume increased to 54.0 million gallons in the fourth quarter of 2016 from 52.2 million gallons in the fourth quarter of 2015. Merchandise margins decreased to 30.5% in the fourth quarter of 2016 from 31.1% in the fourth quarter of 2015. Merchandise sales decreased to $78.9 million in the fourth quarter of 2016 from $81.0 million in the fourth quarter of 2015.

FULL-YEAR 2016

Special items increased net loss by $17.7 million for 2016 primarily as a result of employee retention expenses of $10.7 million, losses of $1.0 million related to an asphalt inventory adjustment, unrealized losses of $14.8 million associated with commodity swaps and $1.7 million associated with losses recognized on disposition of assets, before income tax and non-controlling interest impacts of $10.5 million. Special items reduced net income by $42.7 million for 2015 primarily as a result of a loss on impairment of goodwill of $39.0 million, losses of $8.1 million related to an asphalt inventory adjustment and employee retention expenses of $11.3 million, partially offset by unrealized gains of $7.9 million associated with commodity swaps, insurance recoveries net of professional fees of $3.6 million and $1.9 million associated with gains recognized on disposition of assets, before income tax and non-controlling interest impacts of $2.3 million.

Combined refinery average throughput for 2016 was 139,243 bpd, compared to a combined refinery average throughput of 140,036 bpd in 2015. The Big Spring refinery average throughput for 2016 was 71,363 bpd compared to 74,906 bpd for 2015. The reduced throughput at our Big Spring refinery during 2016 was the result of a reformer regeneration during the first quarter of 2016 and third quarter of 2016. Additionally, throughput was reduced as a result of a catalyst replacement for our diesel hydrotreater unit in the first quarter of 2016 and unplanned downtime during the second quarter of 2016 due to a power outage caused by inclement weather, which affected multiple units. The Krotz Springs refinery average throughput for 2016 was 67,880 bpd compared to 65,130 bpd for 2015. During 2016, the Krotz Springs refinery throughput was impacted by our election to reduce the crude rate in order to optimize the refinery yield, as well as maintenance that was performed on the fluid catalytic cracking unit during the second quarter of 2016. During 2015, we completed the planned major turnaround at the Krotz Springs refinery, which reduced throughput during the period.

Refinery operating margin at the Big Spring refinery was $8.28 per barrel for 2016 compared to $14.43 per barrel for 2015. This decrease in operating margin was primarily due to a lower Gulf Coast 3/2/1 crack spread, a narrowing of the WTI Cushing to WTI Midland spread and increased RINs costs, partially offset by a widening of the WTI Cushing to WTS spread and an increased benefit from the contango market environment which reduced the cost of crude.

Refinery operating margin at the Krotz Springs refinery was $3.06 per barrel for 2016 compared to $7.02 per barrel for 2015. This decrease in operating margin was primarily due to a lower Gulf Coast 2/1/1 high sulfur diesel crack spread, a narrowing of both the WTI Cushing to WTI Midland and the LLS to WTI Cushing spreads and increased RINs costs, partially offset by an increased benefit from the contango market environment which reduced the cost of crude.

The average Gulf Coast 3/2/1 crack spread for 2016 was $12.64 per barrel compared to $17.02 per barrel for 2015. The average Gulf Coast 2/1/1 high sulfur diesel crack spread for 2016 was $7.95 per barrel compared to $10.81 per barrel for 2015.

The average WTI Cushing to WTI Midland spread for 2016 was $0.15 per barrel compared to $0.39 per barrel for 2015. The average WTI Cushing to WTS spread for 2016 was $0.73 per barrel compared to $(0.06) per barrel for 2015. The average LLS to WTI Cushing spread for 2016 was $1.70 per barrel compared to $3.73 per barrel for 2015. The average Brent to WTI Cushing spread for 2016 was $0.21 per barrel compared to $3.54 per barrel for 2015. The average Brent to LLS spread for 2016 was $(1.45) per barrel compared to $0.14 per barrel for 2015.

The average RINs cost effect on the Big Spring refinery operating margin was $0.55 per barrel for 2016, compared to $0.42 per barrel for 2015. The average RINs cost effect on the Krotz Springs refinery operating margin was $1.48 per barrel for 2016, compared to $0.99 per barrel for 2015.

The contango environment in 2016 created an average cost of crude benefit of $1.24 per barrel compared to an average cost of crude benefit of $1.01 per barrel in 2015.

During 2016, our California renewable fuels facility generated an operating margin of $68.67 per barrel from an average of 2,275 barrels per day of throughput. Our statements of operations include operating income of $24.1 million in 2016 related to the facility’s operations.

Asphalt margins for 2016 were $98.80 per ton compared to $105.70 per ton in 2015. On a cash basis (i.e. excluding inventory effects), asphalt margins in 2016 were $100.94 per ton compared to $109.35 per ton in 2015.

Retail fuel margins decreased to 19.8 cents per gallon in 2016 from 21.3 cents per gallon in 2015. Retail fuel sales volume increased to 209.0 million gallons in 2016 from 199.1 million gallons in 2015. Merchandise margins decreased to 31.2% in 2016 from 31.9% in 2015. Merchandise sales decreased to $324.4 million in 2016 from $328.5 million in 2015.

Alon also announced today that its Board of Directors has declared the regular quarterly cash dividend of $0.15 per share. The dividend is payable on March 17, 2017 to stockholders of record at the close of business on March 9, 2017.

CONFERENCE CALL

Alon has scheduled a conference call, which will be broadcast live over the Internet on Friday, February 24, 2017, at 11:30 a.m. Eastern Time (10:30 a.m. Central Time), to discuss the fourth quarter and year-end 2016 financial results. To access the call, please dial 877-407-0672, or 412-902-0003 for international callers, and ask for the Alon USA Energy call at least 10 minutes prior to the start time. Investors may also listen to the conference live by logging on to the Alon investor relations website, http://ir.alonusa.com. A telephonic replay of the conference call will be available through March 3, 2017, and may be accessed by calling 877-660-6853, or 201-612-7415 for international callers, and using the passcode 13652999#. A webcast archive will also be available at http://ir.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. Alon owns 100% of the general partner and 81.6% of the limited partner interests in Alon USA Partners, LP (NYSE: ALDW), which owns a crude oil refinery in Big Spring, Texas, with a crude oil throughput capacity of 73,000 barrels per day and an integrated wholesale marketing business. In addition, Alon directly owns a crude oil refinery in Krotz Springs, Louisiana, with a crude oil throughput capacity of 74,000 barrels per day. Alon also owns crude oil refineries in California, which have not processed crude oil since 2012. Alon owns a majority interest in a renewable fuels facility in California, with a throughput capacity of 3,000 barrels per day. Alon is a leading marketer of asphalt, which it distributes primarily through asphalt terminals located predominately in the Southwestern and Western United States. Alon is the largest 7-Eleven licensee in the United States and operates approximately 300 convenience stores which also market motor fuels in Central and West 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.

 

SOURCE Alon USA Energy, Inc.

Silver Standard Reports Fourth Quarter and Year-End 2016 Results

VANCOUVER, Feb. 23, 2017 /PRNewswire/ – Silver Standard Resources Inc. (NASDAQ: SSRI) (TSX: SSO) (“Silver Standard”) reports consolidated financial results for the fourth quarter and year ended December 31, 2016.

Paul Benson, President and CEO said, “We had a strong fourth quarter capping a year of records for Silver Standard, which included production of over 390,000 gold equivalent ounces at an AISC of less than $925 per ounce. Our focus on Operational Excellence has led not only to production and cost improvements at each site, it has allowed us to meet or exceed our annual guidance for the fifth straight year.”

“Importantly, we entered 2017 in a very strong position with over $325 million in cash and an additional $150 million in marketable securities, which predominantly reflects our near 10% stake in Pretium Resources. Last year, we continued to invest in our business, particularly with respect to exploration, and the success in growing reserves at both Marigold and Seabee is driving our increased brownfields exploration in 2017.”

Fourth Quarter and Year-End 2016 Highlights:
(All figures are in U.S. dollars unless otherwise noted)

Marigold Mine, U.S.

Mine production

In the fourth quarter of 2016, the Marigold mine produced 59,945 ounces of gold, 26% higher than the previous quarter as expected, due to higher grade ore tonnes sourced from the deeper benches of the current Mackay pit phase during the third and fourth quarters of 2016. Higher grade ore was placed on the new leach pad, completed in the third quarter of 2016, which assisted in accelerated gold recovery.

A total of 19.6 million tonnes of material were mined in the fourth quarter of 2016, in line with material mined in the third quarter.  Approximately 6.4 million tonnes of ore were delivered to the heap leach pads at a gold grade of 0.48 g/t. This compares to 4.8 million tonnes of ore delivered to the heap leach pads at a gold grade of 0.42 g/t in the third quarter of 2016. Gold grade mined in the fourth quarter was 14% higher than the third quarter. The strip ratio declined to 2.0:1 in the quarter, a 36% reduction compared to the previous quarter.

In 2016, the Marigold mine produced 205,116 ounces of gold, compared to 207,006 ounces of gold produced in 2015, achieving the mid-point of our improved 2016 production guidance.

Total material mined and ore stacked on leach pads of 75.1 million tonnes and 23.6 million tonnes, respectively, in 2016, were record amounts for the Marigold mine, due to the increased hauling capacity added to the fleet earlier in the year. The grade of the ore delivered to the leach pads in 2016 was 0.45 g/t and the average strip ratio was 2.2:1.

Mine sales

A total of 61,308 ounces of gold were sold at an average price of $1,247 per ounce during the fourth quarter of 2016, an increase of 30% from the 47,278 ounces of gold sold at an average price of $1,330 per ounce during the third quarter of 2016. The increase in sales was a function of increased gold production. Gold sales totaled 204,315 ounces in 2016.

Mine operating costs

Cash costs and AISC per payable ounce of gold sold are non-GAAP financial measures. Please see “Cautionary Note Regarding Non-GAAP Measures”.

Cash costs, which include all costs of inventory, refining costs and royalties, of $585 per payable ounce of gold sold in the fourth quarter of 2016 were lower than cash costs of $636 per payable ounce of gold sold in the third quarter of 2016 due to higher number of ounces stacked lowering the unit costs of inventory. Cash costs decreased in 2016 to $647 per payable ounce of gold sold, compared to $692 per payable ounce of gold sold in 2015, due to the higher number of ounces stacked, improved mining costs and an increase in the proportion of operating costs capitalized to stripping. Costs per tonne mined decreased in 2016 to $1.50 per tonne compared to $1.56 per tonne in 2015 as a result of our increased capacity and improved efficiencies in our loading and hauling practices as well as a lower diesel unit cost. Processing and general and administration unit costs also declined by 4% and 10%, respectively, in 2016 compared to the comparative period, principally due to higher ore tonnes stacked. Operational Excellence remains a core activity at Marigold, particularly focused on maintenance processes and practices.

AISC decreased in the fourth quarter of 2016 to $835 per payable ounce of gold sold from $1,139 in the third quarter of 2016 due to lower capitalized stripping and lower investments in capital. AISC of $960 per payable ounce of gold sold in 2016 increased from $895 in 2015, primarily due to higher capital investments, including the construction of a new leach pad, and higher capitalized stripping.

Exploration

During the fourth quarter Marigold drilled 14,289 meters in 54 reverse circulation (“RC”) drillholes using two RC drills. One core drillhole was completed as part of the deep sulphide exploration program. In 2016, we drilled 55,147 meters in 231 RC drillholes, 955 meters in one core drillhole and assayed 55,073 samples as a part of our program to re-assay historic drill samples (the “Assay Program”). Drill activities for 2016 focused on Mineral Resources to Mineral Reserves conversion around the 8 South pit, Terry Zone North, HideOut, Mud and Valmy pits and Mineral Resources discovery at the Crossfire, East Basalt and Battle Cry targets.  The results of this successful exploration program are discussed in the Mineral Reserves and Mineral Resources section. Drilling in the fourth quarter of 2016 centered on Mineral Resources expansion.

During 2016, we completed the Assay Program, which had the objective of identifying low grade ore that was not included in the existing Mineral Reserves. The samples from the Assay Program are from the planned life of mine production areas. The 2016 Assay Program added 130,000 gold ounces to Indicated Mineral Resources, which are included in our 2016 Mineral Reserves and Mineral Resources statement.

Mineral Resources expansion drilling has exceeded expectations in the East Basalt pit area, where 14 drillholes were completed during the fourth quarter of 2016, with the majority intersecting mineralization at or above Mineral Resources average grade. In addition, drilling adjacent to the dormant Valmy pit continues to demonstrate the presence of higher grade structural trends beyond the south east corner of the pit.

Seabee Gold Operation, Canada

Mine production

The Seabee Gold Operation consists of the Seabee and Santoy underground mines, both of which feed a single processing facility. In the fourth quarter, the Seabee Gold Operation produced 19,711 ounces of gold, largely in line with the 20,142 ounces of gold produced during the third quarter of 2016. Production during the second half of the year of 39,853 ounces of gold exceeded our second half 2016 production guidance range of 32,000 to 35,000 ounces of gold.

A record 84,526 tonnes of ore were milled at an average gold grade of 7.40 g/t and recovery of 97.0% during the fourth quarter. This compares to a total of 82,756 tonnes of ore milled at an average gold grade of 7.40 g/t and recovery of 96.5% in the third quarter.

During the fourth quarter, the mill was maintained at a higher throughput of 919 tonnes per day, a record quarterly performance. The Santoy complex mined approximately 92% of total ore milled, with the remainder mined from Seabee. Mining continued to transition to long hole stope ore from Santoy and we are reviewing the mine plan to determine the feasibility of higher, sustainable production rates.

During the period since acquisition, from May 31, 2016 to December 31, 2016, the Seabee Gold Operation produced a total of 46,574 ounces of gold.

Mine sales

A total of 17,229 ounces of gold were sold at an average price of $1,230 per ounce during the fourth quarter of 2016. This compares to 21,911 ounces of gold sold in the third quarter of 2016 at an average realized price of $1,334 per ounce.

In the period from acquisition to December 31, 2016, we sold 50,446 ounces of gold at an average price of $1,271 per payable gold ounce sold.

Mine operating costs

Cash costs and AISC per payable ounce of gold sold are non-GAAP financial measures. Please see “Cautionary Note Regarding Non-GAAP Measures”.

Cost of sales and income from mine operations includes the effects of non-cash amortization charges related to purchase price accounting upon our acquisition of Claude Resources in 2016.

Cash costs per payable ounce of gold sold, which include all costs of inventory, refining costs and royalties, were $595 in the fourth quarter of 2016, lower than the $661 in the third quarter of 2016 due to timing of inventory costing and higher capital development. Cash costs for the period from acquisition to December 31, 2016, were $639 per payable ounce of gold sold.

AISC per payable ounce of gold sold were $833 in the fourth quarter of 2016, comparable to $840 in the third quarter of 2016, while capital spending remained modest, and higher exploration spending consistent with our objective of adding Mineral Reserves and Mineral Resources at the mine, offset the lower cash costs. AISC for the period from acquisition to December 31, 2016, were $823 per payable ounce of gold sold.

Exploration

For 2016, the Seabee Gold Operation planned 65,000 meters of underground drilling and 18,000 meters of surface drilling with the objective to increase and convert Mineral Resources to Mineral Reserves. During the fourth quarter of 2016, we completed 21,705 meters of underground diamond drilling to upgrade Inferred Mineral Resources and explore further the extensions to the Santoy 8A and Santoy Gap deposits. From surface, we completed 7,702 meters of drilling to upgrade the up plunge extension of the Santoy Gap 9A, 9B and 9C Mineral Resources and to complete deeper infill drilling on the Santoy 8A Inferred Mineral Resources. The results of this successful exploration program are discussed in the Mineral Reserves and Mineral Resources section.

On October 6, 2016, we announced an option agreement to acquire up to an 80% interest in the adjacent Fisher property which lies south on strike from the ore deposits at Santoy Gap and Santoy 8A. This agreement doubles our prospective land position at the Seabee Gold Operation and planning for our 2017 exploration work is underway with surface exploration drilling expected in the second half of the year.

Pirquitas Mine, Argentina

Mine production

In the fourth quarter of 2016, Pirquitas production declined relative to the third quarter, as expected, producing 2.2 million ounces of silver.

Ore was milled at an average rate of 5,175 tonnes per day in the fourth quarter, 5% higher than the previous quarter and a record quarterly result. Additionally, the average milling rate was 29% above the mill’s nominal design of 4,000 tonnes per day, which is the result of a successful 14-month Operational Excellence project. Ore milled in the fourth quarter of 2016 contained an average silver grade of 194 g/t, 27% lower than the 264 g/t reported in the third quarter as the availability of ore in the lower benches of the San Miguel open pit was reduced, resulting in medium grade stockpile ore supplementing mill feed.

The average silver recovery in the fourth quarter was 74.5%, lower than the 79.0% recovery in the previous quarter, in line with reduced silver mill feed grade that resulted from the increasing proportion of stockpiled material in the mill feed.

In 2016, the Pirquitas mine produced a record 10.4 million ounces of silver, close to the upper end of our increased annual production guidance range. This was largely the result of achieving a 14% increase in daily milling rate during the year. Silver mined grade of 183 g/t was in line with that realized in 2015, while silver mill feed grade was 6% lower than the previous year, in line with expectations as medium grade stockpiled ore supplemented the mill feed. Silver recovery of 77.8% was lower compared to 2015, due to a combination of closing down the zinc circuit in January 2016 and lower silver grade throughout the year. Silver sales totaled 11.4 million ounces in 2016.

Detailed planning and consultation with the workforce, union, communities and government for the cessation of open pit mining was undertaken and mining ceased in January 2017. It is expected that medium grade stockpile material will be processed through the plant in 2017. Low grade stockpiles may be processed in late 2017, and potentially in early 2018, depending on prevailing economic conditions.

Mine sales

Silver sales totaled 2.6 million ounces in the fourth quarter of 2016, an 11% decrease from the third quarter of 2016, due to availability of inventory following lower production in the fourth quarter of 2016. Additionally, we recorded a negative period-end price adjustment for unsettled ounces of $9.2 million, or $3.49 per ounce, compared to a positive adjustment of $0.7 million in the third quarter of 2016.

We sold 11.4 million ounces of silver in 2016, an 11% increase compared to the 10.3 million ounces sold in 2015. Sales of our silver concentrate were also impacted by period-end price adjustments for unsettled ounces which had a negative impact of $1.6 million cumulatively in 2016, compared to the negative impact of $10.6 million in 2015.

Mine operating costs

Cash costs and AISC per payable ounce of silver sold are non-GAAP financial measures. Please see “Cautionary Note Regarding Non-GAAP Measures”.

Cost of sales and income from mine operations in the fourth quarter of 2016 were impacted by non-cash provisions related to the pending cessation of mine operations. We recorded a severance provision of $5.7 million and a non-cash write-down of supplies inventory and VAT of $3.7 million.

Cash costs, which include cost of inventory, treatment and refining costs, and by-product credits, were $9.80 per payable ounce of silver sold in the fourth quarter of 2016, higher than the $8.48 per payable ounce of silver sold in the third quarter of 2016 due to medium grade stockpile ore grade supplementing mined ore and reduced mining efficiency on the lowest benches of the open pit.

Cash costs per payable ounce of silver sold in 2016 decreased to $9.00 from $10.68 in 2015 as our stronger production more than offset the cessation of the zinc recovery circuit which saved cost but lowered overall silver recovery.

AISC per payable ounce of silver sold in the fourth quarter of 2016 were higher at $11.47 than in the third quarter at $9.87 due to higher cash costs and capital investment in the planned phase 5 tailings lift. AISC of $10.21 per payable ounce of silver sold were lower in 2016 than the $12.44 per payable ounce of silver sold in 2015 due to lower cash costs while capital investments remained modest.

Exploration

There was no exploration activity at the Pirquitas mine during 2016 as we focused on advancing the Chinchillas project.

Chinchillas Project, Argentina

During the fourth quarter, hydrology and geotechnical drilling was completed for final feasibility studies. In addition to this work, metallurgical and environmental baseline studies, along with community engagement programs, continued. In the fourth quarter of 2016, we funded approximately $1.6 million for work on the Chinchillas project, bringing total expenditures to date to $12.1 million.

During the second quarter of 2016, Golden Arrow Resources Corporation (“Golden Arrow”) released a revised Mineral Resources estimate and technical report for the Chinchillas project following an infill drilling program of 115 core drillholes comprising 15,142 meters of drilling. As part of the continuing engineering studies, a program of condemnation drilling commenced beneath areas selected for major infrastructure, such as the waste rock facility.

We are undertaking the relevant engineering studies to determine the economic viability of the Chinchillas project as a satellite mine feeding the Pirquitas plant and extending the life of the operation. Our option agreement with Golden Arrow requires the notice of exercise of the option to be given by March 30, 2017. A decision with regards to such notice is subject to the remaining technical evaluation, which is scheduled for completion in the first quarter of 2017, as well as our assessment of market conditions and country risks, including the status of our export duty litigation.

Export duties

We entered into a fiscal stability agreement (the “Fiscal Agreement”) with the Federal Government of Argentina in 1998 for production from the Pirquitas mine. In December 2007, the National Customs Authority of Argentina (Dirección Nacional de Aduanas) (“Customs”) levied an export duty of approximately 10% from concentrate for projects with fiscal stability agreements pre-dating 2002 and Customs has asserted that the Pirquitas mine is subject to this duty. We have challenged the legality of the export duty applied to silver concentrate and the matter is currently under review by the Federal Court (Jujuy) in Argentina.

The Federal Court (Jujuy) granted an injunction in our favor effective September 29, 2010, that prohibited Customs from withholding the 10% export duty on silver concentrate (the “Injunction”), pending the decision of the courts with respect to our challenge of the legality of the application of the export duty. On June 21, 2016 the Federal Court (Jujuy) ruled that the Injunction would remain in place subject to certain conditions, including the provision by August 5, 2016, of a guarantee by Silver Standard against liabilities arising from export duties and applicable interest as well as security from Mina Pirquitas, LLC on certain assets at the Pirquitas mine. We appealed the condition to provide the parent guarantee. On November 17, 2016 the Appeal Court in Salta ruled in favour of the Federal Tax Authority and lifted the Injunction. Our subsequent request for appeal of this ruling to the Supreme Court was approved by the Appeal Court in Salta on December 27, 2016 and the suspension of payment under the Injunction remains in effect. We are also continuing discussions with the Federal Tax Authority and other government officials for potential resolution of the claim. We cannot predict the outcome of the court proceedings and those discussions. If we do not reach a successful resolution of the matter, the Federal Tax Authority may make further application to the court to have the Injunction lifted and initiate proceedings to collect the accrued export duties and its claimed interest. The lifting of the Injunction does not impact our underlying challenge of the legality of the application of export duties or remedies available under the Fiscal Agreement. Changes in our assessment of this matter could result in material adjustments to our consolidated statements of income (loss).

Outlook

This section of the news release provides management’s production, cost, capital, exploration and development expenditure estimates for 2017. See “Cautionary Note Regarding Forward-Looking Statements.”

For the full year 2017, we expect:

In 2017, on a consolidated basis at mid-point of guidance, we expect to produce 355,000 gold equivalent ounces at gold equivalent cash costs of $735 per ounce. Cash costs and capital guidance are based on $55 per barrel oil price and 1.30 Canadian to U.S. dollar exchange rate. Gold equivalent figures are based on $1,250 per ounce gold price and $17.50 per ounce silver price.

Marigold production is expected to increase compared to 2016 as the mine benefits from the gold ounces stacked on the leach pads through the latter months of 2016 and from continued strong performance in 2017. As a result, production is expected to be weighted towards the first half of the year. Capital expenditures total $30 million and are primarily attributable to mining equipment components of $17 million and replacement of support equipment of $5 million, with $2.5 million allocated for permitting. Capitalized stripping is expected to decline significantly relative to 2016 as mining focuses on the current phases of the Mackay pit. Approximately $11 million of capitalized stripping is expected to be incurred in the second half of the year as we commence stripping of the next phase of the Mackay pit.  Despite the decline in mining costs capitalized, cash costs per payable ounce are expected to be similar to 2016. The mine has encountered severe weather conditions through the initial weeks for the first quarter of 2017 that have caused periodic interruptions and inefficiencies to mine and heap leach operations.

At the Seabee Gold Operation, 2017 will mark our first full year of ownership with production expected to remain near record levels of between 72,000 and 82,000 ounces of gold at low cash costs, based on mill throughput of 900 tonnes per day. Annual production is expected to be weighted toward the second half of the year as mine grade is expected to increase as additional levels are developed at the Santoy mine complex through early 2017. Capital investments at Seabee of $8 million include $2 million for improvement of gravity recovery in the plant, $2 million for ventilation improvements to the Santoy mine complex to support a higher mining rate and $3 million for a water treatment plant related to tailings water discharge. Capitalized development of $11 million is principally for Santoy decline development and to establish stations for underground definition and exploration drilling.

At the Pirquitas mine, mining of the San Miguel open pit ceased in January 2017. Medium grade stockpiles currently constitute the mill feed upon cessation of open pit mining activities. As a result, silver production is expected to decline and cash costs are expected to be higher in 2017, compared to 2016. Zinc production is not expected in 2017 due to lower zinc grades in the stockpiled material. As we report cash costs on a per payable ounce sold basis, 2017 expected cash costs include stockpile inventory costs of approximately $3.50 per ounce of silver that were previously incurred. Capital expenditures include approximately $1 million for completion of the tailings facility lift, which commenced in the fourth quarter of 2016 and is scheduled for completion in the first quarter of 2017. The remaining sustaining capital is for maintaining the re-handle fleet and the mill in fully operational condition.  Further, we expect to incur approximately $6 million related to remediation of mining areas in 2017, mainly on surface water control measures. The Pirquitas plant is expected to operate through 2017, conditional upon profitable processing of stockpiles at prevailing market conditions, and to close in late 2017 or early 2018, subject to our investment decision on the Chinchillas project.

Exploration and development expenditures are forecast at $18 million for 2017, an increase of $3 million from our previous disclosures. Approximately $5 million of exploration at Marigold is for Mineral Resource discovery and conversion of Mineral Resources to Mineral Reserves, with a particular focus on the Valmy property. At the Seabee Gold Operation, $5 million of expenditures are to be incurred targeting conversion of Mineral Resources to Mineral Reserves at Santoy Gap and Santoy 8 as well as Mineral Resource discovery adjacent to the Seabee mine, along the Santoy Shear trend, and at multiple targets present on existing Seabee Gold Operation claims and on the contiguous Fisher property, where we hold an option. The remaining expenditures are attributable to our development portfolio, including $1 million at the Perdito early-stage exploration property, where we hold an option, and $3 million for the recently agreed earn-in option letter of intent with Eskay Mining Corp.

Consolidated Financial Summary

Quarterly financial summary

The 41% increase in quarterly revenue in the fourth quarter of 2016 compared to the fourth quarter of 2015 was due to 15% and 14% higher realized prices of gold and silver, respectively, combined with a 13% increase in gold equivalent ounces sold to 110,130, largely due to sales from the acquired Seabee Gold Operation and stronger sales from the Pirquitas mine.

Income from mine operations in the fourth quarter of 2016 generated a gross margin of 22%, significantly higher than the negative 23% gross margin in the fourth quarter of 2015 due to higher precious metals prices, lower cost of sales, particularly at the Pirquitas mine, and the addition of the Seabee Gold Operation. Income from mine operations in the fourth quarter of 2016 included a severance provision of $5.7 million related to the closure of the Pirquitas mine and $3.7 million in non-cash write downs of supplies inventory and VAT receivable. Loss from mine operations in the fourth quarter of 2015 was negatively impacted by a non-cash write-down of stockpile inventory to its net realizable value (“NRV”) at the Pirquitas mine in the amount of $7.7 million, a $12.2 million non-cash provision against supplies inventory and a $4.7 million severance provision related to the Pirquitas mine. Operating loss in the fourth quarter of 2015 was also negatively impacted by a $13.9 million non-cash impairment of plant and equipment at the Pirquitas mine.

In the fourth quarter of 2016 we generated a gain of $6.5 million from the sale of the Parral properties in Mexico and the Diablillos project in Argentina. We did not sell any mineral properties in the comparative quarter of 2015. Additionally, in the fourth quarter of 2016 we incurred withholding taxes of $4.9 million on the repatriation of funds from Argentina due to the strong cash generation of the Pirquitas mine during 2016.

Cash generated by operating activities increased significantly to $74.1 million in the fourth quarter of 2016 compared to $20.5 million in the fourth quarter of 2015. The higher prices of gold and silver and the higher volumes sold at lower unit costs generated significantly higher cash from operating activities. We used $24.0 million in investing activities in the fourth quarter of 2016 compared to $10.6 million in the fourth quarter of 2015. Investments in the fourth quarter of 2016 increased compared to the fourth quarter of 2015 due to the addition of the Seabee Gold Operation, a tailings lift build at the Pirquitas mine and a high quarter of capitalized stripping at the Marigold mine. Capitalized stripping at the Marigold mine was $10.2 million and underground development at the Seabee Gold Operation was $2.4 million.

Annual financial summary

The increase in revenue in 2016 compared to 2015, of 31%, resulted from 18% higher sales of gold equivalent ounces due to sales from the newly-acquired Seabee Gold Operation, strong performance at the Pirquitas mine and 10% and 7% higher prices of gold and silver, respectively.

Income from mine operations in 2016 generated a gross margin of 31%, higher than the 5% in 2015, mainly due to higher precious metals prices and lower cost of sales, particularly at the Pirquitas mine. Income from mine operations in 2016 was negatively impacted by a severance provision related to the Pirquitas mine of $5.7 million and by $3.7 million of non-cash write downs of inventory and VAT receivable. Income from mine operations in 2015 was also negatively impacted by a severance provision related to the Pirquitas mine of $4.7 million and by the non-cash write-down of stockpile and supplies inventory at the Pirquitas mine of $27.6 million. Operating income in 2016, was also significantly higher than in the comparative period which was negatively impacted by a $48.4 million impairment of the Pirquitas mine.

Cash generated from operating activities was $170.7 million in 2016, compared to $74.1 million in 2015 as a result of improved margins at Marigold and Pirquitas and the addition of the strong cash producing Seabee Gold Operation in May 2016. In 2016, we invested $5.4 million in underground development at the Seabee Gold Operation, $32.6 million in capitalized stripping primarily at the Marigold mine and $42.3 million in total at our operations for plant and equipment. In 2015, we invested $37.3 million in plant and equipment and $12.5 million in capitalized stripping, mainly at the Marigold mine. Overall, cash used in investing activities was slightly lower in 2016, than in 2015 at $43.3 million. Cash used in financing activities in the year includes repayment of Claude Resources’ $13.7 million credit facility, full repayment of the short-term debt in Argentina offset by the receipt of $6.7 million from the exercise of stock options. There were limited financing cash flows in 2015.

Corporate Summary

In 2016, the tax dispute with the Canada Revenue Agency (“CRA”) was settled in our favor. On August 24, 2016, the CRA issued a new notice of reassessment for each of our 2010 and 2011 taxation years reversing the Notice of Reassessment issued to us in January 2015 and, on September 2, 2016, refunded $18.2 million being the deposit we paid to the CRA to appeal, plus accrued interest from the date of payment of the deposit. Following the receipt of the deposit, with accrued interest, the Department of Justice filed a notice of discontinuance of our appeal with the Tax Court of Canada.

On August 19, 2016, we sold 100% of our Juncal and La Flora projects in Region II, Chile to Austral Gold Limited (ASX: AGD) for aggregate consideration of $250,000 in cash and a 1.0% net smelter return royalty on production from the projects.

On October 31, 2016, we completed the sale of 100% of our Parral properties in Chihuahua, Mexico, including the Veta Colorada, La Palmilla, and San Patricio properties (collectively, the “Parral properties”) to Endeavour Silver Corp. (TSX: EDR and NYSE: EXK) (“Endeavour Silver”) for $5.3 million of Endeavour Silver shares and the right to receive $0.2 million of Endeavour Silver shares for each 1 million silver ounces included in an estimate of Measured and Indicated Mineral Resources prepared by Endeavour Silver in respect of the San Patricio and La Palmilla properties, plus a 1% net smelter royalty on all mineral products from the San Patricio and La Palmilla properties.

On November 1, 2016, we completed the sale of our Diablillos and M-18 projects, located in Argentina, to Huayra Minerals Corporation (“Huayra”) for cash payments of approximately $1.5 million over the first two years and $12.5 million over the following three to five years, a 19.9% equity stake in Huayra, with free carried interest until the completion of a financing of $5.0 million or more, and a 1% net smelter returns royalty on production from each of the projects.

Subsequent to the year end, in January 2017, we also agreed to option our Candelaria property in Nevada, U.S. to Silver One Resources Inc. (TSXV: SVE, OTC: SLVR and FRA: BRK1.F) (“Silver One”) for $1.0 million of Silver One shares issued on January 20, 2017, and three annual installments of $1.0 million in shares of Silver One.

On February 13, 2017, we announced the signing of a definitive agreement to sell our Berenguela project in Peru to Valor Resources Limited (ASX: VAL) (“VRL”) for aggregate cash payments of $12.0 million over five years, a 9.9% equity stake in VRL, with a free carry interest until VRL completes, in aggregate, a financing of $8 million and a 1% net smelter royalty on all metal production from the property.

Mineral Reserves and Mineral Resources

At December 31, 2016, total Proven and Probable gold Mineral Reserves were 3.49 million ounces and total Proven and Probable silver Mineral Reserves were 16.8 million ounces. Mineral Reserves estimates for the Marigold mine, the Seabee Gold Operation and the Pirquitas mine have been determined based on prices of $1,250 per ounce of gold and $18.00 per ounce of silver. These prices are an increase from prices of $1,100 per ounce of gold and $16.00 per ounce of silver used to determine our Mineral Reserves estimate for the Marigold mine and the Pirquitas mine as at December 31, 2015, reflecting market conditions and consensus long-term metal prices.

At December 31, 2016, our total Measured and Indicated Mineral Resources (inclusive of Mineral Reserves) were 6.9 million ounces of gold and 608.4 million ounces of silver and our Inferred Mineral Resources were 1.93 million ounces of gold and 40.4 million ounces of silver. Mineral Resources estimates have been determined based on prices of $1,400 per ounce of gold and $22.50 per ounce of silver. These prices remain unchanged from prices used to determine Mineral Resources estimates as at December 31, 2015.

At Marigold, positive exploration results and discoveries led to increases in each of Mineral Reserves, Mineral Resources and Inferred Mineral Resources. Probable Mineral Reserves increased by 31% to 2.84 million ounces of gold, after accounting for mining depletion and changes to gold price and cost assumptions, while gold grade remained unchanged at 0.45 g/t. The increase in Probable Mineral Reserves is attributable to our successful infill drill program which converted Mineral Resources at Terry Zone North (310,000 gold ounces), HideOut (130,000 gold ounces) and 8 South pit extension zone (210,000 gold ounces), collectively referred to as Mackay North; at Valmy, where 200,000 gold ounces were added; and through our Assay Program which added 110,000 gold ounces. The higher price of gold utilized had a marginal impact on Probable Mineral Reserves. Indicated Mineral Resources increased by 12% to 5.15 million ounces of gold. The increase in Indicated Mineral Resources (inclusive of Mineral Reserves) is attributed to additions of approximately 450,000 gold ounces at the Mackay North areas, 260,000 gold ounces from the East Basalt/Battle Cry/Antler areas on the Valmy property, 110,000 gold ounces from drilling at the Valmy pit and 130,000 gold ounces from the Assay Program. Overall, Inferred Mineral Resources increased by 27% to 700,000 ounces of gold mainly due to additions at Mackay North and East Basalt.

At the Seabee Gold Operation, Proven and Probable Mineral Reserves total 360,000 ounces of gold, a 50% increase compared to year-end 2015 as a result of conversion and development drilling. Average grade has increased to 8.2 g/t gold due to the addition of higher grade Mineral Reserves from Santoy 8.  Proven and Probable Mineral Reserve increases are due to additions of 77,000 gold ounces at Santoy 8 and 107,000 gold ounces at Santoy Gap. Measured and Indicated Mineral Resources (inclusive of Mineral Reserves) total 570,000 gold ounces at year-end 2016, reflecting the conversion from 89,000 gold ounces at Santoy 8 and 149,000 gold ounces at Santoy Gap from Inferred Mineral Resources. As at December 31, 2016, Inferred Mineral Resources total 640,000 gold ounces, reflecting a 37% decline due to conversion to Mineral Reserves in the second half of 2016.

At Pirquitas, Probable Mineral Reserves declined to 9.6 million ounces of silver due to mine depletion and are contained principally in surface stockpiles. Measured and Indicated Mineral Resources (inclusive of Mineral Reserves) total 67.4 million ounces of silver within the open pit, underground and stockpile inventory. Inferred Mineral Resources total 8.4 million ounces of silver at December 31, 2016.

Details on Mineral Reserves and Mineral Resources by mine including tonnes, grades, ounces and notes, are presented in the table below.

Mineral Reserves and Resources
(As of December 31, 2016)

Notes to Mineral Reserves and Mineral Resources Table:

All estimates set forth in the Mineral Reserves and Mineral Resources table have been prepared in accordance with National Instrument 43-101 – Standards of Disclosure for Mineral Projects (“NI 43-101”). The estimates of Mineral Reserves and Mineral Resources for each property other than the Marigold mine, the Seabee Gold Operation and the Amisk gold project have been reviewed and approved by Bruce Butcher, P.Eng., our Director, Mine Planning, and F. Carl Edmunds, P.Geo., our Chief Geologist, each of whom is a Qualified Person.

Mineral Resources are reported inclusive of Mineral Reserves. Mineral Resources that are not Mineral Reserves do not have demonstrated economic viability. Due to the uncertainty that may be attached to Inferred Mineral Resources, it cannot be assumed that all or any part of an Inferred Mineral Resource will be upgraded to an Indicated or Measured Mineral Resource as a result of continued exploration.

Mineral Resources and Mineral Reserves figures have some rounding applied, and thus totals may not sum exactly. All ounces reported herein represent troy ounces, and “g/t” represents grams per tonne. All $ references are in U.S. dollars.  All Mineral Reserve and Mineral Resource estimates are as of December 31, 2016.

Metal prices utilized for Mineral Reserves estimates are $1,250 per ounce of gold, $18.00 per ounce of silver and $1.00 per pound of zinc, except as noted below for the San Luis project. Metal prices utilized for Mineral Resources estimates are $1,400 per ounce of gold, $22.50 per ounce of silver, $1.10 per pound of zinc and $3.00 per pound of copper, except as noted below for the San Luis project and the Amisk gold project.

The table does not include an estimate of Mineral Resources for the Diablillos project, which we sold to Huayra effective as of November 1, 2016, or the Berenguela project, which we agreed to sell to VRL, as announced in our news release dated February 13, 2017.

All technical reports for the properties are available under our profile on the SEDAR website at www.sedar.com or on our website at www.silverstandard.com.

Marigold

Seabee Gold Operation

Pirquitas

San Luis

Pitarrilla

Amisk

Qualified Persons

Except as otherwise set out herein, the scientific and technical information contained in this news release relating to the Marigold mine has been reviewed and approved by Thomas Rice and James N. Carver, each of whom is a SME Registered Member and a Qualified Person under NI 43-101. Mr. Rice is our Technical Services Manager and Mr. Carver is our Chief Geologist at the Marigold mine. The scientific and technical data contained in this news release relating to the Seabee Gold Operation has been reviewed and approved by Cameron Chapman, P.Eng., and Jeffrey Kulas, P. Geo., each of whom is a Qualified Person under NI 43-101. Mr. Chapman is our General Manager and Mr. Kulas is our Manager Geology, Mining Operations at the Seabee Gold Operation. The scientific and technical information contained in this news release relating to the Pirquitas mine has been reviewed and approved by Bruce Butcher, P.Eng., and F. Carl Edmunds, P. Geo., each of whom is a Qualified Person under NI 43-101. Mr. Butcher is our Director, Mine Planning and Mr. Edmunds is our Chief Geologist.

Management Discussion & Analysis and Conference Call

This news release should be read in conjunction with our audited consolidated financial statements and the MD&A as filed with the Canadian Securities Administrators and available at www.sedar.com or our website at www.silverstandard.com.

About Silver Standard

Silver Standard is a Canadian-based precious metals producer with three wholly-owned and operated mines, including the Marigold gold mine in Nevada, U.S., the Seabee Gold Operation in Saskatchewan, Canada and the Pirquitas silver mine in Jujuy Province, Argentina. We also have two feasibility stage projects and an extensive portfolio of exploration properties throughout North and South America. We are committed to delivering safe production through relentless emphasis on Operational Excellence. We are also focused on growing production and Mineral Reserves through the exploration and acquisition of assets for accretive growth, while maintaining financial strength.

For further information contact:
W. John DeCooman, Jr.
Vice President, Business Development and Strategy
Silver Standard Resources Inc.
Vancouver, BC
N.A. toll-free: +1 (888) 338-0046
All others: +1 (604) 689-3846
E-Mail: invest@silverstandard.com

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Cautionary Note Regarding Forward-Looking Statements:

This news release contains forward-looking information within the meaning of Canadian securities laws and forward-looking statements within the meaning of the U.S. Private Securities Litigation Reform Act of 1995 (collectively, “forward-looking statements”). All statements, other than statements of historical fact, are forward-looking statements.

Generally, forward-looking statements can be identified by the use of words or phrases such as “expects,” “anticipates,” “plans,” “projects,” “estimates,” “assumes,” “intends,” “strategy,” “goals,” “objectives,” “potential,” “believes,” or variations thereof, or stating that certain actions, events or results “may,” “could,” “would,” “might” or “will” be taken, occur or be achieved, or the negative of any of these terms or similar expressions. The forward-looking statements in this news release relate to, among other things: future production of gold, silver and other metals; future costs of inventory, and cash costs, total costs and AISC per payable ounce of gold, silver and other metals sold; expected exploration and development expenditures; the prices of gold, silver and other metals; the timing of cessation of stockpile processing at the Pirquitas mine; estimated expenses relating to remediation at Pirquitas; the effects of laws, regulations and government policies affecting our operations or potential future operations; future successful development of our projects; the expected timing to complete engineering studies at the Chinchillas project and make a decision about whether to move forward with the project; the sufficiency of our current working capital, anticipated operating cash flow or our ability to raise necessary funds; estimated production rates for gold, silver and other metals produced by us; timing of production and the cash costs, total costs and AISC of production at the Marigold mine, the Seabee Gold Operation and the Pirquitas mine; the estimated cost of sustaining capital; ongoing or future development plans and capital replacement, improvement or remediation programs; the expected benefits of the new leach pad at the Marigold mine; the estimates of expected or anticipated economic returns from our mining projects, including future sales of metals, concentrate or other products produced by us; our ability to expand Mineral Resources and convert Mineral Resources into Mineral Reserves; and our plans and expectations for our properties and operations.                          

These forward-looking statements are subject to a variety of known and unknown risks, uncertainties and other factors that could cause actual events or results to differ from those expressed or implied, including, without limitation, the following: uncertainty of production, development plans and cost estimates for the Marigold mine, the Seabee Gold Operation, the Pirquitas mine and our projects; our ability to replace Mineral Reserves; subject to exercising our election to proceed, our ability to complete and successfully integrate Golden Arrow’s Chinchillas project, on a joint venture basis, into our current operations; commodity price fluctuations; political or economic instability and unexpected regulatory changes; currency fluctuations; the possibility of future losses; general economic conditions; fully realizing the value of our shareholdings in Pretium Resources Inc. and our other marketable securities, due to changes in price, liquidity or disposal cost of such marketable securities; potential export duty and related interest on past production and sales of silver concentrate from the Pirquitas mine; counterparty and market risks related to the sale of our concentrate and metals; uncertainty in the accuracy of Mineral Reserves and Mineral Resources estimates and in our ability to extract mineralization profitably; differences in U.S. and Canadian practices for reporting Mineral Reserves and Mineral Resources; lack of suitable infrastructure or damage to existing infrastructure; future development risks, including start-up delays and cost overruns; our ability to obtain adequate financing for further exploration and development programs and opportunities; uncertainty in acquiring additional commercially mineable mineral rights; delays in obtaining or failure to obtain governmental permits, or non-compliance with our permits; our ability to attract and retain qualified personnel and management; potential labour unrest, including labour actions by our unionized employees at the Pirquitas mine; the impact of governmental regulations, including health, safety and environmental regulations, including increased costs and restrictions on operations due to compliance with such regulations; reclamation and closure requirements for our mineral properties; failure to effectively manage our tailings facilities; social and economic changes following closure of a mine, including the expected closure of the Pirquitas mine in 2017, may lead to adverse impacts and unrest; unpredictable risks and hazards related to the development and operation of a mine or mineral property that are beyond our control; indigenous peoples’ title claims and rights to consultation and accommodation may affect our existing operations as well as development projects and future acquisitions; assessments by taxation authorities in multiple jurisdictions; claims and legal proceedings, including adverse rulings in litigation against us and/or our directors or officers; compliance with anti-corruption laws and internal controls, and increased regulatory compliance costs; complying with emerging climate change regulations and the impact of climate change, including extreme weather conditions; recoverability of deferred consideration to be received in connection with recent divestitures; uncertainties related to title to our mineral properties and the ability to obtain surface rights; the sufficiency of our insurance coverage; civil disobedience in the countries where our mineral properties are located; operational safety and security risks; actions required to be taken by us under human rights law; competition in the mining industry for mineral properties; shortage or poor quality of equipment or supplies; an event of default under our Notes may significantly reduce our liquidity and adversely affect our business; failure to meet covenants under our senior secured revolving credit facility; conflicts of interest that could arise from certain of our directors’ involvement with other natural resource companies; information systems security threats; and those other various risks and uncertainties identified under the heading “Risk Factors” in our most recent Annual Information Form filed with the Canadian securities regulatory authorities and included in our most recent Annual Report on Form 40-F filed with the U.S. Securities and Exchange Commission (“SEC”).

This list is not exhaustive of the factors that may affect any of our forward-looking statements. Our forward-looking statements are based on what our management considers to be reasonable assumptions, beliefs, expectations and opinions based on the information currently available to it. Assumptions have been made regarding, among other things, our ability to carry on our exploration and development activities, our ability to meet our obligations under our property agreements, the timing and results of drilling programs, the discovery of Mineral Resources and Mineral Reserves on our mineral properties, the timely receipt of required approvals and permits, including those approvals and permits required for successful project permitting, construction and operation of our projects, the price of the minerals we produce, the costs of operating and exploration expenditures, our ability to operate in a safe, efficient and effective manner, our ability to obtain financing as and when required and on reasonable terms, and our ability to continue operating the Marigold mine, the Seabee Gold Operation and the Pirquitas mine. You are cautioned that the foregoing list is not exhaustive of all factors and assumptions which may have been used. We cannot assure you that actual events, performance or results will be consistent with these forward-looking statements, and management’s assumptions may prove to be incorrect. Our forward-looking statements reflect current expectations regarding future events and operating performance and speak only as of the date hereof and we do not assume any obligation to update forward-looking statements if circumstances or management’s beliefs, expectations or opinions should change other than as required by applicable law. For the reasons set forth above, you should not place undue reliance on forward-looking statements.

Cautionary Note to U.S. Investors

This news release includes Mineral Reserves and Mineral Resources classification terms that comply with reporting standards in Canada and the Mineral Reserves and the Mineral Resources estimates are made in accordance with NI 43-101. NI 43-101 is a rule developed by the Canadian Securities Administrators that establishes standards for all public disclosure an issuer makes of scientific and technical information concerning mineral projects. These standards differ significantly from the requirements of the SEC set out in Industry Guide 7. Consequently, Mineral Reserves and Mineral Resources information included in this news release is not comparable to similar information that would generally be disclosed by domestic U.S. reporting companies subject to the reporting and disclosure requirements of the SEC. Under SEC standards, mineralization may not be classified as a “reserve” unless the determination has been made that the mineralization could be economically produced or extracted at the time the reserve determination is made.

In addition, the SEC’s disclosure standards normally do not permit the inclusion of information concerning “Measured Mineral Resources,” “Indicated Mineral Resources” or “Inferred Mineral Resources” or other descriptions of the amount of mineralization in mineral deposits that do not constitute “reserves” by U.S. standards in documents filed with the SEC. U.S. investors should understand that “Inferred Mineral Resources” have a great amount of uncertainty as to their existence and great uncertainty as to their economic and legal feasibility. Moreover, the requirements of NI 43-101 for identification of “reserves” are also not the same as those of the SEC, and reserves reported by us in compliance with NI 43-101 may not qualify as “reserves” under SEC standards. Accordingly, information concerning mineral deposits set forth herein may not be comparable with information made public by companies that report in accordance with U.S. standards.

Cautionary Note Regarding Non-GAAP Measures

This news release includes certain terms or performance measures commonly used in the mining industry that are not defined under International Financial Reporting Standards (“IFRS”), including cash costs, total costs and AISC per payable ounce of precious metals sold, realized metal prices, adjusted income (loss) before tax, adjusted income tax (expense), adjusted net income (loss) and adjusted basic earnings (loss) per share. Non-GAAP financial measures do not have any standardized meaning prescribed under IFRS and, therefore, they may not be comparable to similar measures reported by other companies. We believe that, in addition to conventional measures prepared in accordance with IFRS, certain investors use this information to evaluate our performance. The data presented is intended to provide additional information and should not be considered in isolation or as a substitute for measures of performance prepared in accordance with IFRS. These non-GAAP measures should be read in conjunction with our consolidated financial statements. Readers should refer to “Non-GAAP and Additional GAAP Financial Measures” in section 13 of our MD&A, available under our corporate profile at www.sedar.com or on our website at www.silverstandard.com, for a more detailed discussion of how we calculate such measures and for a reconciliation of such measures to IFRS terms.

SOURCE Silver Standard Resources Inc.