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UNAUDITED SUPPLEMENTAL OIL AND GAS INFORMATION
 12 Months Ended
Dec. 31, 2015
Oil and Gas Exploration and Production Industries Disclosures [Abstract]  
UNAUDITED SUPPLEMENTAL OIL AND GAS INFORMATION
17. UNAUDITED SUPPLEMENTAL OIL AND GAS INFORMATION

 

Oil and Gas Reserves (Unaudited)

 

Proved reserves are estimated quantities of oil, NGLs and natural gas which geological and engineering data demonstrate with reasonable certainty to be recoverable in future years from known reservoirs under existing economic and operating conditions. Oil and gas prices used are the average price during the 12-month period prior to the effective date of the report, determined as an unweighted arithmetic average of the first-day-of-the-month price for each month within such period, unless prices are defined by contractual arrangements. Proved developed reserves are reserves that can reasonably be expected to be recovered through existing wells with existing equipment and operating methods. The Company emphasizes that reserve estimates are inherently imprecise and that estimates of new discoveries and undeveloped locations are more imprecise than estimates of established producing oil and gas properties. Accordingly, these estimates are expected to change as future information becomes available.

 

Proved oil and gas reserve quantities at December 31, 2015, 2014 and 2013 and the related discounted future net cash flows before income taxes are based on the estimates prepared by Jane E. Trusty for 2015 and by Cawley, Gillespie & Associates, Inc. for 2014 and 2013. Such estimates have been prepared in accordance with guidelines established by the Securities and Exchange Commission. All of the Company’s estimated proved reserves are located in the United States.

 

The Company’s estimated quantities of proved oil and gas reserves and changes in net proved reserves are summarized below for the years ended December 31, 2015, 2014 and 2013:

 

    2015     2014     2013  
    Oil     Gas     Oil     Gas     Oil     Gas  
    (bbls)     (mcfe) (1)     (bbls)     (mcfe) (1)     (bbls)     (mcfe) (1)  
                                     
Total proved reserves:                                                
Reserve quantities, beginning of year     4,119,736       3,211,245       3,459,713       2,371,908       2,613,643       1,798,088  
Revisions of previous estimates     (2,377,364 )     (206,912 )     (262,570 )     802,241       (162,957 )     382,690  
Discoveries and extensions     94,458       27,102       1,583,292       1,006,659       1,352,746       678,412  
Sale of minerals in place     -       -       (330,871 )     (156,482 )     -       -  
Production     (221,650 )     (553,505 )     (329,828 )     (813,081 )     (343,719 )     (487,282 )
                                                 
Reserve quantities, end of year     1,615,180       2,477,930       4,119,736       3,211,245       3,459,713       2,371,908  
                                                 
Proved developed reserves, end of year     1,248,750       2,068,190       1,754,668       1,892,446       1,875,528       1,701,282  

 

  (1) Mcf equivalents (Mcfe) consist of natural gas reserves in mcf plus NGLs converted to mcf using a factor of 6 mcf for each barrel of NGL.

 

Standardized Measure (Unaudited)

 

The Company computes a standardized measure of future net cash flows and changes therein relating to estimated proved reserves in accordance with authoritative accounting guidance. The assumptions used to compute the standardized measure are those prescribed by the FASB and the SEC. These assumptions do not necessarily reflect the Company’s expectations of actual revenues to be derived from those reserves, nor their present value amount. The limitations inherent in the reserve quantity estimation process, as discussed previously, are equally applicable to the standardized measure computations since these reserve quantity estimates are the basis for the valuation process.

 

Future cash inflows and production and development costs are determined by applying prices and costs, including transportation, quality, and basis differentials, to the year-end estimated future reserve quantities. The following prices as adjusted for transportation, quality, and basis differentials were used in the calculation of the standardized measure:

 

    2015     2014     2013  
                   
Oil per Bbl   $ 43.54     $ 85.63     $ 91.06  
Gas per Mcfe (1)   $ 3.36     $ 8.84     $ 6.41  

 

  (1) Consists of the weighted average price for natural gas in mcf plus NGL’s converted to mcf using a factor of 6 mcf for each barrel of NGL.

 

Future operating costs are determined based on estimates of expenditures to be incurred in developing and producing the proved reserves in place at the end of the period using year-end costs and assuming continuation of existing economic conditions. Estimated future income taxes are computed using the current statutory income tax rates, including consideration for estimated future statutory depletion. The resulting future net cash flows are reduced to present value amounts by applying a 10 percent annual discount factor.

 

The standardized measure of discounted future net cash flows relating to the Company’s proved oil and gas reserves is as follows as of December 31, 2015, 2014 and 2013:

 

    2015     2014     2013  
                   
Future cash inflows   $ 78,646     $ 381,156     $ 330,245  
Future cash outflows:                        
Production costs     (44,685 )     (149,450 )     (129,392 )
Development costs     (8,050 )     (70,770 )     (37,739 )
Income taxes     -       (12,719 )     (14,500 )
                         
Future net cash flows     25,911       148,217       148,614  
10% annual discount factor     (8,143 )     (66,328 )     (43,761 )
                         
Standardized measure of discounted future net cash flows   $ 17,768     $ 81,889     $ 104,853  

 

Changes in Standardized Measure (Unaudited)

 

The changes in the standardized measure of future net cash flows relating to proved oil and gas reserves for the years ended December 31, 2015, 2014 and 2013 are as follows:

 

    2015     2014     2013  
                   
Standardized measure, beginning of year   $ 81,889     $ 104,853     $ 71,017  
Sales of oil and gas, net of production costs     (2,944 )     (21,741 )     (23,178 )
Net changes in prices and production costs     (96,586 )     (17,376 )     2,543  
Changes in estimated future development costs     51,998       (1,869 )     (6,414 )
Extensions and discoveries     2,260       14,706       54,360  
Sale of minerals in place     -       (13,339 )     -  
Revisions in previous quantity estimates     (27,693 )     (4,815 )     (2,961 )
Previously estimated development costs incurred     -       7,175       8,344  
Net changes in income taxes     3,306       6,924       (4,245 )
Accretion of discount     8,189       10,090       7,647  
Changes in timing and other     (2,651 )     (2,719 )     (2,260 )
                         
Standardized measure, end of year   $ 17,768     $ 81,889     $ 104,853