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Synergy Resources Reports Fiscal Fourth Quarter and Year End 2013 Results

PLATTEVILLE, CO--(Marketwired - November 05, 2013) - Synergy Resources Corporation (NYSE MKT: SYRG), a U.S. oil and gas exploration and production company focused on the Denver-Julesburg Basin, reported its fiscal fourth quarter and year end results for the period ended August 31, 2013.

Fiscal Fourth Quarter and Year 2013 Financial Highlights as Compared to the Same Year Ago Periods

  • Revenue increased 117% to $14.7 million in the fourth quarter, and was up 85% to $46.2 million for the full year.
  • Operating Income increased 95% to $6.7 million in the quarter, and was up 66% to $19.5 million for the full year vs. $11.8 million in fiscal 2012.
  • Net income was $1.0 million or $0.01 per diluted share in the quarter and $9.6 million or $0.16 per diluted share for the full year as compared to net income of $12.1 million or $0.25 per diluted share in fiscal 2012. Net income in fiscal 2013 includes deferred income tax expense of $6.8 million and an unrealized loss on commodity derivatives of $2.6 million.
  • Adjusted EBITDA was up 86% to a record $33.8 million in fiscal 2013, representing a 73% return on revenue for the full year (see further discussion about the presentation of adjusted EBITDA in "About Non-GAAP Financial Measures," below).
  • As of August 31, 2013, the company's cash, equivalents and short term investments totaled $79.5 million, as compared to $19.3 million at August 31, 2012. The current ratio at August 31, 2013 was 2.2 to 1.

Operational Highlights

  • In the fourth quarter, net oil and natural gas production increased 95% to 228,042 barrels of oil equivalent (BOE), as compared to the same year-ago quarter, and averaged 2,479 BOE per day versus an average of 1,270 BOE in the year ago quarter.
  • Brought 27 new operated vertical wells on-line during the year.
  • Participated in 21 non-operated horizontal wells during the year.
  • Increased estimated proved reserves to 7 million barrels of oil and 40.7 billion cubic feet of gas, or combined total BOE of 13.8 million. The estimated present value of these reserves before tax and discounted at 10% is $236 million. Total BOE increased 30%, and present value increased by 59%, as compared to the annual reserve report prepared on August 31, 2012.

Fiscal Fourth Quarter as Compared to Fiscal Third Quarter

Results for the 2013 fiscal fourth quarter improved compared to the third quarter. Revenues were $14.7 million, up from $12.3 million in the third quarter. We attribute the increase in revenues to a combination of higher production and higher commodity prices. Realized oil prices averaged $92.32 per barrel in the fourth quarter versus $83.98 in the third quarter, and the average realized price per mcf for natural gas was $5.06 in Q4 compared to $4.76 in Q3. Operating income for the fourth quarter was $6.7 million, up from $4.9 million in the previous quarter. Net income totaled $1.0 million or $0.01 per diluted share, down from $3.6 million or $0.06 per diluted share in the third quarter. During the fourth quarter, there was a significant change in the value of our commodity hedge position, resulting in non-cash charges for an unrealized loss of $3.0 million, compared to an unrealized gain of $0.5 million during the third quarter. Adjusted EBITDA in the fourth quarter was $10.6 million, up 14% from $9.3 million in the previous quarter.

The following table presents certain per unit metrics that compare results of the corresponding quarterly and annual reporting periods:

Per Unit Metric   Three Months Ended         Years Ended      
    August 31,   August 31,         August 31,   August 31,      
Sales Volumes   2013   2012   % Change     2013   2012   % Change  
Oil (Bbls)     125,045     72,361   73 %     421,265     235,691   79 %
Gas (Mcf)     617,979     266,744   132 %     2,107,603     1,109,057   90 %
Barrels of oil equivalent (BOE)     228,042     116,818   95 %     772,532     420,534   84 %
BOE per day     2,479     1,270   95 %     2,117     1,149   84 %
Revenues (in thousands)                                    
Oil   $ 11,544   $ 5,998   92 %   $ 36,206   $ 20,644   75 %
Gas     3,130     752   316 %     10,017     4,325   132 %
  Total   $ 14,674   $ 6,750   117 %   $ 46,223   $ 24,969   85 %
Average sales price                                    
Oil ($/Bbls)   $ 92.32   $ 82.89   11 %   $ 85.95   $ 87.59   (2 %)
Gas ($/Mcf)   $ 5.06   $ 2.82   80 %   $ 4.75   $ 3.90   22 %
Barrels of oil equivalent ($/BOE) $ 64.35   $ 57.78   11 %   $ 59.83   $ 59.37   1 %
Average costs per BOE                                    
Lease operating expense   $ 4.67   $ 2.91   60 %   $ 4.42   $ 2.88   53 %
Production taxes   $ 5.53   $ 5.03   10 %   $ 5.48   $ 5.79   (5 %)
DD&A expense   $ 17.63   $ 12.07   46 %   $ 17.26   $ 14.29   21 %
G&A expense   $ 7.35   $ 8.54   (14 %)   $ 7.36   $ 8.46   (13 %)

Operational Results for the Fourth Fiscal Quarter and Year 2013

In fiscal year 2013, the company reported that it had drilled and brought into production 27 vertical wells. It also drilled 5 operated horizontal wells, 3 Niobrara B bench and 2 Codell wells, on its Renfroe pad that were in final stages of completion at the end of the fiscal year and were brought into production during its fiscal first quarter of 2014. Additionally the company participated as a non-operating owner in 21 horizontal wells during the fiscal year, 11 of which were brought into production representing 2.36 net wells to the company's working interest. 

The company completed the acquisition of assets from Orr Energy for $42 million which added to its acreage position in the Wattenberg Field and increased the number of potential horizontal drilling locations.

With the exception of two wells, all of the company's production is in the Wattenberg Field of the D-J Basin. As of August 31, 2013, the company operated 218 gross wells (202 net) and holds an ownership interest in 75 gross wells (22 net) operated by other companies.

In the fourth quarter of the fiscal year the company amended its turn-key drilling contract with Ensign Drilling to drill an additional 21 horizontal wells targeting the Niobrara and Codell formations in the D-J Basin. At the end of the fiscal year the company had drilled 2 of the contracted wells and subsequent to year end has drilled 5 additional wells on the Leffler pad. After finishing on the Leffler pad the rig will move to the Phelps pad to begin drilling the next six wells.

Management Commentary

Ed Holloway, the CEO of Synergy Resources commented, "Fiscal 2013 was another positive year of growth for Synergy achieving an 84% increase in production despite not bringing into production any new operated wells during the second half of the year while we switched from vertically focused drilling operations to horizontal drilling. We also demonstrated our ability to make acquisitions and increase our lease hold foot print at very competitive prices. Synergy now has over 22,000 net acres in the Greater Wattenberg Area. We continued our disciplined low cost approach to our operations as evidenced through our drilling and completion of the Renfroe horizontal wells for less than $4 million per well, well below the costs of our peers. We also strengthened our balance sheet with our equity offering in the fourth quarter and are positioned to execute our fiscal 2014 cap-ex budget with cash on hand and estimated internal cash flow. Additional liquidity is available under our credit facility to take advantage of future opportunities."

Fiscal 2014 Outlook

Management anticipates updated CAPEX spending of $157.5 million on the following programs with the vast majority of the drilling expenditures weighted towards the horizontal drilling program in the Wattenberg Field. The company anticipates funding this program with cash on hand and cash flow from revenues.

  • $96 million to drill 24 new horizontal wells as operator
  • $4 million to drill 6 new vertical wells as operator
  • $22.5 million to participate as a non-operator to drill approximately 5 net horizontal wells to Synergy's interest
  • $5 million for land leasing
  • $30 million cash for acquisitions

Conference Call

Synergy Resources will host a conference call today, Tuesday, November 5, 2013 at 11:00 a.m. Eastern time (9:00 a.m. Mountain time) to discuss its fiscal fourth quarter and year end 2012 results. President and CEO Ed Holloway, Vice President William Scaff, Jr. CFO Monty Jennings, and VP of Operations Craig Rasmuson, will host the presentation, followed by a question and answer period.
Date: Tuesday, November 5, 2013
Time: 11:00 a.m. Eastern time (9:00 a.m. Mountain time)
Domestic Dial-In Number: 1-877-407 9122
International Dial-In Number: 1-201-493-6747

The conference call will be webcast simultaneously which you can access via this link: http//syrginfo.equisolvewebcast.com/q4-2013 and via the investor section of the company's web site at www.syrginfo.com.
Please call the conference telephone number 5 to 10 minutes prior to the start time. An operator will register your name and organization. If you have any difficulty connecting with the conference call, please contact Jon Kruljac with Synergy Resources at 970-737-1073.
A replay of the call will be available after 3:00 p.m. ET on the same day and until November 19, 2013.
Toll-free replay number: 1-877-660-6853
International replay number: 1-201-612-7415
Replay ID #: 411931

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 Denver-Julesburg Basin, which encompasses Colorado, Wyoming, Kansas, and Nebraska. The Wattenberg field in the D-J Basin ranks as one of the most productive fields in the U.S. The company's corporate offices are located in Platteville, Colorado. More company news and information about Synergy Resources is available at www.SYRGinfo.com.

Important Cautions Regarding Forward-Looking Statements

This press release may contain forward-looking statements, within the meaning of the Private Securities Litigation Reform Act of 1995. The use of words such as "believes", "expects", "anticipates", "intends", "plans", "estimates", "should", "likely" or similar expressions, indicates a forward-looking statement. 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; and the volatility of the company's stock price.

About Reserve Estimates

Reserve estimates mentioned in this release were prepared in accordance with guidelines established by the Securities and Exchange Commission for proved reserves. Probable and possible reserves are excluded. Prices are based on a trailing twelve month average and are held constant over the life of the properties. Similarly, costs are held constant for the duration of the well.

About Non-GAAP Financial Measures
The company uses "adjusted EBITDA," as a non-GAAP financial measure to evaluate financial performance such as period-to-period comparisons. This Non-GAAP measure is not defined under U.S. GAAP and should be considered in addition to, not as a substitute for, indicators of financial performance reported in accordance with U.S. GAAP. The company may use non-GAAP measures that are not comparable to measures with similar titles reported by other companies. Also, in the future, the company may disclose different non-GAAP financial measures in order to help investors more meaningfully evaluate and compare the company's future results of operations to its previously reported results. The company encourages investors to review its financial statements and publicly-filed reports in their entirety and not rely on any single financial measure. The section titled "Reconciliation of Non-GAAP Financial Measures" includes a detailed description of this measure as well as a reconciliation to its most similar U.S. GAAP measure.

Financial Statements

Condensed financial statements are included below. Additional financial information, including footnotes that are considered an integral part of the financial statements, will be included in Synergy's Edgar Filings at www.sec.gov on Form 10-K for the period ended August 31, 2013.

(unaudited, in thousands)
   August 31   August 31
    2013   2012
Cash and short term investments  $ 79,481   $ 19,284
Other current assets    12,494     7,183
  Total current assets    91,975     26,467
Oil and gas properties and equipment    197,965     92,702
Other assets    1,296     1,562
    Total assets  $ 291,236   $ 120,731
Current liabilities $ 41,367   $ 15,592
Revolving credit facility   37,000     3,000
Deferred tax liability   6,538     -
Asset retirement obligations   2,777     1,027
Other liabilities   334     -
  Total liabilities   88,016     19,619
Shareholders' equity:          
  Common stock and paid-in capital   216,454     123,928
  Accumulated deficit   (13,234)     (22,816)
    Total shareholders' equity   203,220     101,112
      Total liabilities and shareholders' equity $ 291,236   $ 120,731
(unaudited, in thousands, except shares and per share data)  
  Three Months Ended August 31   Year Ended August 31,  
  2013     2012   2013   2012  
Oil and gas revenues $ 14,674     $ 6,750   $ 46,223     $ 24,969  
  Lease operating expenses   1,065       164     3,417       1,212  
  Production taxes   1,262       764     4,237       2,436  
  Depreciation, depletion, and amortization   4,020       1,410     13,336       6,010  
  General and administrative   1,675       998     5,688       3,557  
    Total expenses   8,022       3,336     26,678       13,215  
Operating income   6,652       3,414     19,545       11,754  
Other income (expense):                            
  Commodity derivative loss   (3,430 )     -     (3,044 )     -  
  Interest income (expense), net   24       10     (50 )     38  
  Total other income (expense)   (3,406 )     10     (3,094 )     38  
Income before income taxes   3,246       3,424     16,451       11,792  
Provision for income tax (or refund)   2,250       1,477     6,870       (332 )
Net income $ 996     $ 1,947   $ 9,581     $ 12,124  
Net income per common share:                            
  Basic $ 0.02     $ 0.04   $ 0.17     $ 0.26  
  Diluted $ 0.01     $ 0.04   $ 0.16     $ 0.25  
Weighted average shares outstanding:                            
  Basic   66,283,325       51,409,340     57,089,362       46,587,558  
  Diluted   70,176,105       53,072,619     59,088,761       48,359,905  
For the years ended August 31, 2013 and 2012  
(unaudited, in thousands)  
  2013     2012  
Cash flows from operating activities:          
  Net income $ 9,581     $ 12,124  
  Adjustments to reconcile net income to net cash              
  provided by operating activities:              
    Depreciation, depletion, and amortization   13,336       6,010  
    Provision for deferred taxes (or refund)   6,870       (332 )
    Stock-based compensation   1,362       473  
    Unrealized decrease in value of commodity derivatives   2,649       -  
    Changes in operating assets and liabilities   (1,678 )     2,977  
  Total adjustments   22,539       9,128  
  Net cash provided by operating activities   32,120       21,252  
Cash flows from investing activities:              
  Acquisition of property and equipment   (80,469 )     (46,680 )
  Purchase of short term investments   (60,000 )     -  
    Net cash used in investing activities   (140,469 )     (46,680 )
Cash flows from financing activities:              
  Equity financing activities   74,528       37,421  
  Debt financing activities   34,000       (2,200 )
    Net cash provided by financing activities   108,528       35,221  
Net increase in cash and equivalents   179       9,793  
Cash and equivalents at beginning of period   19,284       9,491  
Cash and equivalents at end of period $ 19,463     $ 19,284  

Reconciliation of Non-GAAP Financial Measures
The company defines adjusted EBITDA as net income adjusted to exclude the impact of interest expense, interest income, income taxes, depreciation, depletion and amortization, stock based compensation, and the plus or minus change in fair value of derivative assets or liabilities. The company believes adjusted EBITDA is relevant because it is a measure of cash flow available to fund capital expenditures and service debt and is a metric used by some industry analysts to provide a comparison of its results with its peers. The following table presents a reconciliation of the company's non-GAAP financial measures to the nearest GAAP measure

(unaudited, in thousands)  
  Three Months Ended  
  August 31, 2013     August 31, 2012     May 31, 2013  
Adjusted EBITDA:                
  Net income $ 996     $ 1,947     $ 3,615  
  Depreciation, depletion, and amortization   4,020       1,410       3,820  
  Provision for deferred income tax   2,250       1,477       1,701  
  Stock based compensation   368       150       611  
  Change in fair value of commodity derivative   3,017       -       (502 )
  Interest and related items, net   (24 )     (10 )     89  
    Adjusted EBITDA $ 10,627     $ 4,974     $ 9,334  
    Year Ended          
    August 31, 2013       August 31, 2012          
Adjusted EBITDA:                      
  Net income $ 9,581     $ 12,124          
  Depreciation, depletion, and amortization   13,336       6,010          
  Provision for deferred income tax   6,870       (332 )        
  Stock based compensation   1,362       473          
  Change in fair value of commodity derivative   2,649       -          
  Interest and related items, net   50       (38 )        
    Adjusted EBITDA $ 33,848     $ 18,237