Quantcast

Double Eagle Petroleum Co. Reports Full-Year 2013 Financial Results

March 12, 2014

DENVER, March 12, 2014 /PRNewswire/ – Double Eagle Petroleum Co. (NASDAQ: DBLE) today reported its financial and operating results for the year ended December 31, 2013. The Company reported a net loss attributable to common stock of $16,796,000, or $1.48 per share for 2013 as compared to a net loss of $14,050,000, or $1.25 per share for 2012.

Clean earnings, a non-GAAP financial measure, totaled $10,167,000, or $0.90 per share, for the year ended December 31, 2013, as compared to $15,200,000 or $1.35 per share for the year ended December 31, 2012. Clean earnings excludes the effects on net loss of non-cash charges, consisting of depreciation, depletion and amortization expense, unrealized gains and losses related to the Company’s economic hedges, impairment charges and stock-based compensation expense. Clean earnings also excludes the impact of income taxes, as the Company does not expect to pay income tax in the foreseeable future due to its net operating loss carryforwards. Please see the table at the end of this release for the reconciliation of clean earnings to GAAP net loss.

The Company’s 2013 results were impacted by the following:

Pricing.
The Company benefited from an 11% increase in its average realized natural gas prices, increasing to $3.91 per Mcfe in 2013 from $3.52 per Mcfe in 2012.

Production.
Production totaled 9.2 Bcfe for the year ended December 31, 2013, representing a 12% decrease from 2012.

The Company experienced a 14% decrease in its average daily net production at the Catalina Unit as compared to the prior year, which was primarily the result of a series of equipment challenges experienced in 2013, including a compressor failure and unscheduled maintenance on several injection pumps. Coalbed methane gas wells are susceptible to water saturation when offline and the Company’s operations team has focused its efforts on increasing production given these challenges. As a result of these efforts, the Company realized a sequential increase of 9% in its average daily net production in the fourth quarter of 2013 as compared to the third quarter of 2013. The Company also completed a workover program in the third quarter of 2013, which focused on opening-up the Almond formation in 12 existing Catalina wells. The sequential production growth in the fourth quarter of 2013 is also partially attributable to the success from this workover program.

The Company also experienced a decrease in production from its non-operated properties in the Spyglass Hill Unit and on the Pinedale Anticline. The operator of the Spyglass Hill Unit completed 27 new wells in late 2013. Production from the new wells was not significant in 2013 due to the water management systems. The operator has announced that it has a robust drilling program planned for 2014, which includes six water injection wells and improvements to the water management system.

Non-cash gain/loss on derivative instruments.
The Company had an unrealized non-cash loss from its derivatives of $6,656,000 in 2013, resulting from the net changes in the fair values of its commodity contracts and interest rate swap in 2013. This compared to an unrealized non-cash loss of $7,933,000 in 2012.

Impairment charges.
The Company recorded additional impairment charges related to its Niobrara exploration well totaling $4,812,000 during the year ended December 31, 2013. The Company is currently producing gas from the Niobrara formation, and is awaiting a permit that will also allow natural gas production from the Frontier and Dakota formations in the third quarter of 2014.

Reserves

The Company had estimated proved reserves of 74.7 Bcfe as of December 31, 2013, with a PV-10 value of $78,183,000. Estimated proved reserves were 97% natural gas, of which 80% were proved developed. Approximately 63% of the Company’s 2013 production was replaced through revisions of estimates and extensions and discoveries. The positive revisions were largely due to an increase in the average natural gas price used in the reserve estimate, as calculated in accordance with the Securities and Exchange Commission (“SEC”). SEC pricing increased 38% to $3.53 per MMbtu in 2013 as compared to $2.56 per MMbtu in 2012. As a result of the higher pricing, certain of the Company’s undeveloped well locations on the Pinedale Anticline, which were excluded from our 2012 estimate, became economic. The increase from the Pinedale Anticline reserves was partially offset by downward revisions to the reserves from the Company’s Atlantic Rim properties. The downward revision in the Atlantic Rim is a reflection of the lower production volumes from these properties in 2013 due to the previously discussed operational challenges.

Using the forward strip as of December 31, 2013, the Company estimates its proved reserves to be 91.9 Bcfe with a PV-10 value of $99,355,000. Please refer to the table at the end of this release for additional information on this non-GAAP metric.

Hedging Activity

The Company continues to benefit from its hedging program, realizing prices above the prevailing market prices in both 2013 and 2012. Excluding the impact of its commodity hedges which settled during the year, the Company’s per Mcf realized natural gas price was $3.22 and $2.32 for the years ended December 31, 2013 and 2012, respectively. The Company has historically entered into forward sales contracts, collars and fixed price swaps to manage the price risk associated with its natural gas production. All of the hedging contracts the Company enters require no initial cash payments. The table below summarizes the Company’s open derivative contracts as of December 31, 2013.

    Type of Contract       Remaining      Term     Price
                          Contractual
                          Volume (Mcf)
    ---                   -----------

    Fixed Price Swap         1,825,000 01/14-12/14   $4.27

    Costless Collar          1,800,000 01/14-12/14   $4.00 floor

                                                     $4.50 ceiling

    Fixed Price Swap         1,800,000 01/14-12/14   $4.20

    Fixed Price Swap           540,000 01/14-12/14   $4.17

    Total 2014 Contracted
     Volumes                 5,965,000
                             ---------

    Fixed Price Swap         3,000,000 01/15-12/15   $4.28

    Fixed Price Swap         3,600,000 01/15-12/15   $4.15

    Total 2015 Contracted
     Volumes                 6,600,000
                             ---------

    Fixed Price Swap         1,830,000 01/16-12/16   $4.07

    Total 2016 Contracted
     Volumes                 1,830,000
                             ---------

    Total Contracted
     Volumes                14,395,000
                            ==========

    (1)     All contracts are
            indexed to the New
            York Mercantile
            Exchange

Liquidity and Capital Investment

The Company had $47,450,000 outstanding on its credit facility as of December 31, 2013, at an average interest rate of 3.3%. The Company generated cash flow from operations of $13,082,000 as compared to $19,468,000 for years ended December 31, 2013 and 2012, respectively.

Form 10-K and Earnings Conference Call

Please refer to the Company’s Form 10-K, which will be filed with the Securities and Exchange Commission on March 13, 2014, for a more detailed discussion of the Company’s results.

Double Eagle will host a conference call to discuss it 2013 year end results on March 13, 2014 at 11:00 a.m. Eastern Time (9 a.m. Mountain). Those wanting to listen and participate in the question and answer portion can call (800) 434-1335 and use conference code 567915#.

A replay of this conference call will be available for one week by calling (800) 704-9804 and using pass code * then 567915#.

                           SUMMARY CONSOLIDATED STATEMENTS OF OPERATIONS

                          (In thousands, except share and per share data)

                                      Year Ended December 31,

                                                             2013               2012
                                                             ----               ----

    Revenues

         Oil and gas
          sales                                           $31,784            $26,574

         Transportation
          revenue                                           3,745              4,999

         Price risk
          management
          activities, net                                    (730)             4,939

         Other income,
          net                                                 520              1,653
                                                              ---              -----

         Total revenues                                    35,319             38,165
                                                           ------             ------

    Expenses

         Lease operating
          expenses                                         13,135             12,299

         Production taxes                                   3,906              3,000

         Pipeline
          operating
          expenses                                          5,194              4,892

         Exploration
          expenses
          including dry
          holes                                               181                696

         Impairment and
          abandonment

         of equipment and
          properties                                        4,992              4,988
                                                            -----              -----

         Total expenses                                    27,408             25,875
                                                           ------             ------

    Gross margin
     percentage                                              22.4%              32.2%

         General and
          administrative                                    5,395              6,209

         Depreciation,
          depletion and
          amortization                                     20,942             20,216

         Interest
          expense, net                                      1,307              1,610
                                                            -----              -----

    Pre-tax loss                                          (19,733)           (15,745)

         Deferred tax
          benefit                                           6,660              5,418
                                                            -----              -----

         Net loss                                         (13,073)           (10,327)

         Preferred stock
          requirements                                     (3,723)            (3,723)
                                                           ------             ------

    Net loss
     attributable

      to common stock                                    $(16,796)          $(14,050)
                                                         ========           ========

    Net loss per
     common share:

         Basic and
          Diluted                                          $(1.48)            $(1.25)
                                                           ======             ======

    Weighted average
     shares
     outstanding:

         Basic and
          Diluted                                      11,332,129         11,250,513
                                                       ==========         ==========


                     SELECTED BALANCE SHEET DATA

                           (In thousands)

                                           December 31,

                                          2013             2012  % Change
                                          ----             ----

    Total assets                      $132,400         $158,810           -17%

    Outstanding balance on
     credit facility                    47,450           47,450             0%

    Total stockholders'
     equity                             27,311           43,470           -37%

                      SELECTED CASH FLOW DATA

                          (In thousands)

                                    Year Ended December 31,

                                          2013             2012  % Change
                                          ----             ----

    Net cash provided by

         operating activities          $13,082          $19,468           -33%

    Net cash used in

         investing activities          (10,523)         (25,773)          -59%

    Net cash provided (used) by

         financing activities           (3,830)           1,697          -326%

                     SELECTED OPERATIONAL DATA

                                    Year ended December 31,

                                          2013             2012  % Change
                                          ----             ----

    Total production (Mcfe)          9,211,802       10,514,841           -12%

    Average price realized
     per Mcfe                            $4.12            $3.70            11%

Use of Non-GAAP Financial Measures

The Company believes that the presentation of “clean earnings” below provides a meaningful non-GAAP financial measure to help management and investors understand and compare operating results and business trends among different reporting periods on a consistent basis, independent of regularly reported non-cash charges. The measure also excludes the impact of income taxes because the Company does not expect to pay taxes in the near future due to its net operating loss carryforwards. The Company’s management also uses clean earnings in its planning and development of target operating models and to enhance its understanding of ongoing operations. Readers should not view clean earnings as being superior to, or an alternative to, GAAP results or as being comparable to results reported or forecasted by other companies. A reconciliation of GAAP net income with clean earnings for the years ended December 31, 2013 and 2012, is as follows:

                                          Year ended
                                         December 31,

                                        2013             2012
                                        ----             ----

    Net loss as reported

         under US GAAP              $(16,796)        $(14,050)

    Add back non-cash items:

       Provision for income taxes     (6,660)          (5,418)

    Depreciation, depletion,
     amortization and accretion
     expense                          21,218           20,404

    Non-cash loss on derivative
     instruments (1)                   6,656            7,933

    Share-based compensation
     expense                             744            1,341

    Impairments & abandonments         4,992            4,988

    Other non-cash items                  13                2

    Clean earnings                   $10,167          $15,200
                                     =======          =======

    Clean earnings per share           $0.90            $1.35

    Clean earnings per share -
     less non recurring sales of
     property (2)                      $0.85            $1.20

    (1)     Non-cash loss on
            derivatives is
            comprised of an
            unrealized losses from
            the Company's mark-
            to-market derivative
            instruments (both
            commodity contracts
            and interest rate
            swaps), resulting from
            recording the
            instruments at fair
            value at each year
            end.

    (2)     The Company received
            cash proceeds of $500
            from a third party as
            a penalty for opting-
            out of farmout
            agreement at the Main
            Fork Unit during the
            year ended December
            31, 2013.  The Company
            recorded proceeds of
            $1,680 during the year
            ended December 31,
            2012 related to the
            sale of a non-core
            property.

PV-10 is a non-GAAP financial measure and represents the present value of estimated future cash inflows from proved oil and natural gas reserves, less future development and production costs, discounted at 10% per annum to reflect the timing of future cash flows and using 12-month average prices. PV-10 differs from Standardized Measure (a GAAP metric) because it does not include the effects of income taxes on future net revenues. Management uses PV-10 as an arbitrary reserve asset value measure to compare against past reserve bases and the reserve bases of other business entities that are not dependent on the tax-paying status of the entity. Please refer to the Company’s Annual Report on Form 10-K for the year ended December 31, 2013 for a reconciliation of PV-10 to the Standardized Measure.

The Company presents the below reconciliation of GAAP determined reserves and PV-10 values to the forward strip pricing reserves and PV-10 values. The Company believes that the forward strip priced reserves are more representative of the future value of the existing reserves at December 31, 2013:

                                    Reserves (Bcfe)             PV-10

    Reserves as reported
     using SEC Pricing                            74.7            $78,183

         Increase due to price
          (1)                                     17.2             21,172

    Reserves using forward
     strip pricing                                91.9            $99,355
                                                  ====            =======

(1) The average price used for the SEC estimate was $3.53 per Mcf, or $3.24 per Mcf adjusted for quality, transportation fees, and regional price differentials. The average adjusted forward strip price was $3.75 per Mcf.

About Double Eagle

Double Eagle Petroleum Co., which is headquartered in Denver, Colorado, explores, develops, and sells natural gas and crude oil, with natural gas primarily in the Rocky Mountain region. The Company currently has development activities and opportunities in its Atlantic Rim coalbed methane project and on the Pinedale Anticline in Wyoming. Also, exploration potential exists in both its Niobrara acreage in Wyoming and Nebraska, which totals over 70,000 net acres, and in its acreage in Elko County, Nevada.

This release may contain forward-looking statements regarding Double Eagle Petroleum Co.’s future and expected performance based on assumptions that the Company believes are reasonable. No assurances can be given that these statements will prove to be accurate. A number of risks and uncertainties could cause actual results to differ materially from these statements, including, without limitation, decreases in prices for natural gas and crude oil, unexpected decreases in gas and oil production, the timeliness, costs and results of development and exploration activities, unanticipated delays and costs resulting from regulatory compliance, and other risk factors described from time to time in the Company’s Forms 10-K and 10-Q and other reports filed with the Securities and Exchange Commission. Double Eagle undertakes no obligation to publicly update these forward-looking statements, whether as a result of new information, future events or otherwise.

Company Contact:
John Campbell, IR
(303) 794-8445
www.dble.com

SOURCE Double Eagle Petroleum Co.


Source: PR Newswire



comments powered by Disqus