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Press release from CNW Group

Bellatrix Exploration Announces Material Reserves Increases (up 54%) Posting $6.95/boe Finding and Development Costs

Thursday, February 21, 2013

Bellatrix Exploration Announces Material Reserves Increases (up 54%) Posting $6.95/boe Finding and Development Costs02:05 EST Thursday, February 21, 2013TSX: BXECALGARY, Feb. 21, 2013 /CNW/ - Bellatrix Exploration Ltd. ("Bellatrix" or the "Company") announces the results of an independent reserve evaluation effective December 31, 2012. The report was completed by Sproule Associates Limited ("Sproule").  The evaluation encompasses 100% of Bellatrix's oil and gas properties and was prepared in accordance with National Instrument 51-101 Standards of Disclosure for Oil and Gas Activities ("NI 51-101").Bellatrix benefitted from the largest capital program since conversion to a growth-oriented exploration and production company as it grew 54% to a total of 104 million boe proved and probable ("2P") reserves in 2012.In 2012, the Company spent $164 million developing its resource play assets and $14 million (net of dispositions) on acquiring additional Cardium and Notikewin/Falher production and development acreage.  Resultant growth contributed to a 42% increase in the Company's net asset value to $1.07 billion, equivalent to $9.90/share using a 10%/year discount to future net revenue.The Company replaced 702% of total production in 2012 with new proved and probable reserves at a finding, development and acquisition ("FD&A") cost of $4.28/boe, excluding future development capital ("FDC") requirements.  Including FDC requirements, FD&A totaled $6.95/boe.  Annual production was up 40% in 2012, to 6.11 million boe from 4.36 million boe.The Company established a proved ("1P") Recycle Ratio of 2.35X and a 2P Recycle Ratio of 5.02X excluding FDC.As at December 31, 2012 proved plus probable reserves were comprisedof 34.6 million barrels of oil and natural gas liquids as well as 418 billion cubic feet of natural gas, with a 33% liquids weighting on a boe basis.The Company's calculated reserve life index improved to 8.6 years for 1P reserves, 12.4 years for 2P reserves.KEY 2012 ACHIEVEMENTS Twelve months ended December,  20122011ChangeReserves (company interest, mboe)    Proved Developed Producing24,51819,336+26.8 % Total Proved55,49041,818+32.7%   Proved Undrilled/Total Proved56%53%  Total Proved and Probable104,25867,550+54.3%  Probable/Total Proved and Probable47%38% Net Asset Value, per basic share$9.90$7.01+41.4% Twelve months ended December,  20122011ChangeFD&A costs    1P, including FDC ($/boe)$11.77$13.00-9.5% 2P, including FDC ($/boe)$6.95$9.29-25.2% 3 year average 2P, including FDC ($/boe)$9.04 $10.59-14.6%Annual Average Sales Volumes (boe/d)16,68611,954+39.6 %Q4 Average Sales Volumes (boe/d)18,76314,209+32.1 %Exit Production Rate (boe/d)19,50016,141+20.8 %Funds Flow From Operations ($ millions) 1(unaudited)$111.0$94.2+17.8 % Per basic share (unaudited)$1.03$0.91+ 13.2%Reserve Life Index    Proved  8.6 yrs8.0 yrs+7.5% Proved and Probable  12.4 yrs10.0 yrs+24.0%Recycle Ratios1    1P, excluding FDC  2.35 x3.01 x  2P, excluding FDC  5.02 x4.16 x 1 Funds flow from operations is not a recognized term under Canadian generally accepted accounting principles. See "Non-GAAP Measures".2Operating netback includes impact of commodity price risk contractsSELECT 2012 OPERATING RESULTSTo assist in interpretation of the Company's reserves and key achievements, Bellatrix releases select 2012 operating results ahead of full year-end 2012 financial results including data on capital expenditures, cash flow from operating activities, and drilling results.CAPITAL EXPENDITURES            Years ended December 31,($000s)   2012(unaudited)2011Lease acquisitions and retention  8,30316,367Geological and geophysical  290433Drilling and completion costs  118,783141,051Facilities and equipment  36,81118,471   164,187176,322Drilling Incentive Credits  -(827) Exploration and development1  164,187175,495Corporate 2  195268Property acquisitions  20,9663,798 Total capital expenditures - cash  185,348179,561Property dispositions - cash  (6,660)(4,203) Total net capital expenditures - cash  178,688175,358Capital lease additions - non cash  10,0003,700Other - non-cash 3  (285)6,875  Total -  non - cash  9,71510,575   Total capital expenditures  188,403185,9331 Excludes capitalized costs related to decommissioning liabilities expenditures incurred during the year.2 Corporate includes furniture, fixtures and other costs.3 Other includes non-cash adjustments for current year's decommissioning liabilities and share based compensation.  The $185.3 million capital program for the year ended December 31, 2012 was financed from funds flow from operations and bank debt.ACQUISITIONSEffective November 1, 2012, Bellatrix acquired additional highly prospective Cardium and Notikewin/Falher lands and production in the Willesden Green area of Alberta with 500 boe/d of production, 16 gross (11.95 net) sections of Cardium and Mannville prospective lands, 25 net Cardium development locations, 4 net Notikewin/Falher development locations and a 25% working interest in an operated compressor station and gathering system. The purchase price of $21 million was funded using the Company's existing credit facilities.On December 14, 2012, Bellatrix acquired an additional 11 gross and net sections of highly prospective Cardium and Notikewin/Falher lands in the Ferrier area of west central Alberta. This acquisition is anticipated to provide an additional 37 net drilling locations in the Cardium, 9 net locations in the Notikewin/Falher and an additional 66 net locations in the Duvernay formation.DISPOSITIONSDuring the third quarter of 2012, Bellatrix closed on the disposition of a minor non-core property interest in the Wainwright area, Alberta for $4.25 million after adjustments.  This non-operated unit heavy oil property had production of approximately 59 boe/d. The net proceeds from the disposition were initially used to reduce the Company's bank indebtedness, and ultimately were directed toward the development of the Company's Cardium oil resource program.During the second quarter of 2012, Bellatrix closed on the disposition of two minor non-core property interests consisting of the sale of the Girouxville property in Alberta for $0.6 million after adjustments and the sale of the Cypress-Chowade property in British Columbia for $1.4 million after adjustments.  There was no current production from the Girouxville or Cypress-Chowade properties.RECONCILIATION OF CASH FLOW FROM OPERATING ACTIVITIES AND FUNDS FLOW FROM OPERATIONS                Years ended December 31,($000s)   2012(unaudited)2011Cash flow from operating activities  109,32898,192Decommissioning costs incurred  635569Change in non-cash working capital  1,075(4,524)Funds flow from operations1  111,03894,2371 Funds flow from operations is not a recognized term under Canadian generally accepted accounting principles. See "Non-CAAP Measures"Bellatrix generated funds flow from operations of $111.0 million ($1.03 per basic share and $0.96 per diluted share) for the year ended December 31, 2012, an increase of 18% from $94.2 million ($0.91 per basic share and $0.84 per diluted share) for the 2011 year.  Bellatrix's cash flow from operating activities of $109.3 million ($1.02 per basic share and $0.95 per diluted share) for the year ended December 31, 2012 increased approximately 11% from the $98.2 million ($0.95 per basic share and $0.87 per diluted share) generated in the 2011 year.  The increase between the 2012 and 2011 years was principally due to higher net realized gains on the Company's commodity risk management contracts and higher funds from operating netbacks, despite significantly reduced commodity prices, offset partially by increased financing expenses and slightly higher general and administrative expenses in 2012 compared to 2011.Bellatrix maintains a commodity price risk management program to provide a measure of stability to funds flow from operations.  Unrealized mark-to-market gains or losses are non-cash adjustments to the current fair market value of the contract over its entire term and are included in the calculation of net profit.DRILLING RESULTSDuring the 2012 year, Bellatrix posted a 100% success rate drilling and/or participating in 34 gross (26.32 net) wells, resulting in 28 gross (21.32 net) Cardium oil wells, 2 gross (2.0 net) Cardium condensate-rich gas wells, 1 gross (1.0 net) Duvernay gas well, and 3 gross (2.0 net) Notikewin/Falher liquids-rich gas wells.By comparison, Bellatrix drilled or participated in 54 gross (34.84 net) wells during the year ended December 31, 2011, including 39 gross (29.04 net) oil wells, 14 gross (5.79 net) liquids-rich natural gas wells, and 1 gross (0.007 net) dry hole that was drilled in a non-operated oil unit.During fiscal 2012 the Company operated 24 net wells of the 28 net wells reported in the Cardium. The following average initial production ("IP") rates for the first 7 days ("IP 7"), for the first 15 days ("IP15") and the first 30 days ("IP 30") were achieved:Time# of wellsBoe/dIP 724769IP 1524715IP 30246562012 RESERVESBellatrix engaged Sproule to complete a reserve report in accordance with NI 51-101, on 100% of Bellatrix's oil and gas properties effective December 31, 2012.  Sproule's review does not include the impact of Bellatrix's proposed Cardium Joint Venture announced subsequent to the effective date and currently estimated to close on or before April 30, 2013.Highlights of Bellatrix's December 31, 2012 reserves and 2012 reserve additions include:104.3 million boe total company interest proved and probable reserves, and 55.5 million boe total company interest proved reserves as at December 31, 2012, representing 54.3% and 32.7% year over yeargrowth in 2012, respectively.$1,106.9 million net present value of future net revenue of working interest reserves before tax at 10% discount rate up from $722.5 million posted as of December 31, 2011. This growth contributes to a 41.9% increase in Bellatrix's net asset value, as at December 31, 2012 to $9.90 per basic share outstanding based on the Sproule evaluation of proved and probable reserves at a 10% discount rate.702% replacement of production with 2P company interest reserve additions in year ended 2012.$11.77/boe FD&A for proved reserves including changes to future development capital and $9.16/boeFD&A for proved reserves excluding changes to future development capital for the year ended 2012.FD&A of $6.95/boe for total proved and probable reserves including changes to future development and $4.28/boe FD&A for total proved and probable reserves excluding changes to future development capital for the year ended 2012.The 3 year 2P FD&A including FDC was reduced to $9.04/boe.12.4 year reserve life index on a total working interest proved and probable basis at December 31, 2012 based on Sproule's 2013 forecasted average production of 22,888 boe/d.161 gross (96 net) evaluated future undrilled Cardium horizontal locations.56 gross (41 net) evaluated future undrilled Notikewin/Falher horizontal locations. 2012 Reserves   2011 Reserves   Oil & LiquidsNatural GasTotal TotalVariance (mbbls)(mmcf)(mboe) (mboe)%Proved19,722214,60755,490 41,818+32.7%Probable14,921203,07748,767 25,732+89.5%Proved Plus Probable 34,644417,684104,258 67,550+54.3 %NET ASSET VALUE - PROVED PLUS PROBABLEThe following table of net asset value, as at December, 31, 2012, is based on the Sproule evaluation of future net revenue of the Company's proved plus probable reserves before tax, which does not represent fair market value and does not take into account possible reserve additions from reinvestment of cash flow in existing properties.($000's except acre, unit and per unit amounts) PW 0%PW 5%PW 10%PW 15%PW 20%Proved plus ProbableReserves12,321,4251,523,7861,106,930854,404686,480Undeveloped Lands2131,515131,515131,515131,515131,515Value of Seismic319,50019,50019,50019,50019,500Net Debt4(189,577)(189,577)(189,577)(189,577)(189,577)Net Asset Value 62,282,8631,485,2241,068,368815,842647,918      Per Common Share 5- Per Basic Share$21.16$13.77$9.90$7.56$6.011 As evaluated by Sproule as at December 31, 2012  based on forecast prices and costs before income  tax2 As estimated by Bellatrix as at December 31, 2012 based on 206,638 net acres of undeveloped land at an average price of $636.45 per acre. 3 Based on 27.66% of $70.5 million replacement value based on seismic costs on an average of $1,500/km for 2d and $10,000/km2 to buy data.4 The Company's calculation of Net Debt as at December 31, 2012, includes long term debt, the working capital deficiency (excess), and the liability portion of convertible debentures ($50.687 million) and excludes deferred liabilities, long-term commodity contract liabilities, decommissioning liabilities, long-term finance lease obligations and the deferred tax liability. As at December 31, 2012, the principal amount of convertible debentures outstanding was $55.0 million.5 Based on 107.869 million common shares outstanding as at December 31, 2012.6Certain of the information used in the foregoing calculation, including net debt and number of common shares outstanding, is based on unaudited financial information.NET PRESENT VALUE OF FUTURE NET REVENUE ("NPV")The forecast prices used in Sproule's reserve report effective December 31, 2012 (the "Sproule Report") were an average of the forecast prices published by Sproule Associates Ltd., GLJ Petroleum Consultants Ltd. and McDaniel & Associates Consultants Ltd., as at January 1, 2013 (the "Consultants' Average Forecast Prices").  It should not be assumed that the NPV estimated by Sproule represents the fair market value of the reserves.Estimated future net revenues are stated before deducting future estimated site restoration costs but are reduced for estimated future abandonment costs, the Saskatchewan Capital Tax and estimated capital for future development associated with the reserves.  In the Sproule Report, the net total future capital over the life of the reserves associated with the proved reserves is $327.4 million ($288.3 million discounted at 10%)and $524.6 million ($452.1 million discounted at 10%) for the total proved and probable reserves. The change in 2012 net total future capital over the life of the reserves associated with the proved reserves is $63.2   million ($52.7 million discounted at 10%)and $147.8   million ($115.1 million discounted at 10%) for the total proved and probable reserves.SUMMARY OF NPV BEFORE INCOME TAXES1, 2       As at December 31, 20120%5%10%15%20%Proved      Developed producing576,951447,539369,969318,154281,033 Developed non-producing2,0691,4551,069816643 Undeveloped567,611378,161265,854192,681141,884Total proved1,146,631827,154636,891511,651423,561Probable1,174,793696,632470,039342,753262,919Proved Plus ProbableProducing852,644601,470469,850389,410335,260Total proved plus probable2,321,425  1,523,786  1,106,930  854,404  686,4801 Forecast Prices and Costs ($000s), Discounted at (%/year).2 May not add due to rounding. SUMMARY OF NPV AFTER INCOME TAXES1, 2, 3       As at  December 31, 20120%5%10%15%20%Proved      Developed producing574,579446,965369,811318,106281,018 Developed non-producing1,5521,2801,007793634 Undeveloped425,706286,032201,357145,075105,352Total proved1,001,838734,278572,175463,974387,004Probable880,969518,644346,562249,909189,412Proved Plus Probable Producing781,256568,456452,664379,749329,522Total proved plus probable1,882,207   1,252,922    918,737   713,883    576,4171 Forecast Prices and Costs ($000s), Discounted at (%/year).2 May not add due to rounding.3 The after-tax NPV of Bellatrix's oil and gas properties reflects the tax burden on the properties on a stand-alone basis and utilizes corporate tax pools.  It does not consider the business-entity-level tax situation, or tax planning.  It does not provide an estimate of the value at the level of the business entity, which may be significantly different.  Bellatrix's consolidated financial statements and management's discussion and analysis should be consulted for information at the business entity level.PROVED PLUS PROBABLE FD&A COSTS 1, 2           2012201120102010 - 2012AverageExcluding FDC         FD&A Costs, 2P ($/boe)           Exploration and development3 4.295.994.684.95  Acquisitions (excluding dispositions) 4.2112.2420.965.76  Total (including acquisitions) 4.286.064.965.00Including FDC3         FD&A Costs, 2P ($/boe)           Exploration and development 7.319.2612.749.25  Acquisitions (excluding dispositions)  4.21    12.24    20.965.76  Total (including acquisitions) 6.959.2912.899.041 NI 51-101 specifies how finding and development costs should be calculated if they are reported.  Essentially NI 51-101 requires that the exploration and development costs incurred in the year along with the change in estimated future development costs be aggregated and then divided by the applicable reserve additions.  The calculation specifically excludes the effects of acquisitions and dispositions on both reserves and costs.  By excluding the effects of acquisitions and dispositions Bellatrix believes that the provisions f the NI 51-101 do not fully reflect Bellatrix's ongoing reserve replacement costs.  Since acquisitions can have a significant impact on Bellatrix's annual reserve replacement costs, excluding these amounts could result in an inaccurate portrayal of Bellatrix's cost structure.  Accordingly, Bellatrix also provides FD&A costs that incorporate all acquisitions net of any dispositions during the year.  The foregoing calculation is based on working interest reserves.2 Certain of the information used in the foregoing calculation, including exploration and development expenditures and acquisition expenditures is based on unaudited financial information and is subject to audit and may be subject to change as a result. 2010 numbers do not reflect any changes to accounting rules that may have occurred and are based on generally accepted accounting principles prior to adoption of International Financial Reporting Standards ("IFRS") and have not been restated.3 The aggregate of the exploration and development costs incurred in the most recent financial year and the change during that year in estimated future development costs generally will not reflect total finding and development costs related to reserve additions for that year.PROVED FD&A COSTS 1, 2       201220112010  2010-2012AverageExcluding FDC    FD&A Costs, 1P ($/boe)     Exploration and development38.878.288.038.43 Acquisitions (excluding dispositions)12.2015.7127.4114.52 Total (including acquisitions)9.168.378.478.69Including FDC3    FD&A Costs, 1P ($/boe)     Exploration and development11.7312.9715.6713.17 Acquisitions (excluding dispositions)22.4215.7127.4122.33 Total (including acquisitions)     11.77     13.00     15.9413.221 NI 51-101 specifies how finding and development costs should be calculated if they are reported.  Essentially NI 51-101 requires that the exploration and development costs incurred in the year along with the change in estimated future development costs be aggregated and then divided by the applicable reserve additions.  The calculation specifically excludes the effects of acquisitions and dispositions on both reserves and costs.  By excluding the effects of acquisitions and dispositions Bellatrix believes that the provisions of the NI 51-101 do not fully reflect Bellatrix's ongoing reserve replacement costs.  Since acquisitions can have a significant impact on Bellatrix's annual reserve replacement costs, excluding these amounts could result in an inaccurate portrayal of Bellatrix's cost structure.  Accordingly, Bellatrix also provides FD&A costs that incorporate all acquisitions net of any dispositions during the year.  The foregoing calculation is based on working interest reserves.2 Certain of the information used in the foregoing calculation, including exploration and development expenditures and acquisition expenditures is based on unaudited financial information and is subject to audit and may be subject to change as a result. 2010 numbers do not reflect any changes to accounting rules that may have occurredand are based on generally accepted accounting principles prior to adoption of International Financial Reporting Standards ("IFRS") and have not been restated.3 The aggregate of the exploration and development costs incurred in the most recent financial year and the change during that year in estimated future development costs generally will not reflect total finding and development costs related to reserve additions for that year.RESERVE LIFE INDEXBellatrix's reserve life index has been determined for proved and proved plus probable working interest reserves using forecast prices and costs.  The reserve life index for 2012 below is calculated by dividing reserves as at the effective date of the Sproule Report, December 31, 2012, by 2013 forecasted average production of 22,888 boe/d proved plus probable and 17,655 boe/d proved, as set forth in the Sproule Report, representing a measure of the amount of time production could be sustained at the production rates based on the reserves at the applicable point in time.           2012   2011     2010     2009     2008Proved8.68.07.26.46.4Proved and Probable12.410.011.29.410.1RECYCLE RATIO (OPERATING NETBACK1/FD&A COST)As at December 31, 2012ProvedProved andProbableOperating netback before commodity price risk management contracts ($/boe) 1 (unaudited)$19.66$19.66Recycle ratio (excluding change in FDC)2.15x4.59x   Operating netback after commodity price risk management contracts ($/boe) 1  (unaudited)$21.51$21.51Recycle ratio (excluding change in FDC)2.35x5.02x1Operating netback is calculated by deducting transportation, royalties and operating costs from revenue.The recycle ratio is a measure for evaluating the effectiveness of a company's re-investment program. The ratio measures the efficiency of capital investment. It accomplishes this by comparing the operating netback per BOE to that year's reserve FD&A cost per BOE. Since its conversion to a growth oriented exploration and production company, Bellatrix has successfully achieved a recycle ratio in excess of the 2.74 times recorded in 2009 for proved and probable reserves. In 2012, 2011 and 2010 the recycle ratio for proved and probable reserves was 5.02 times, 4.16 times and 4.31 times, respectively.RESERVES RECONCILIATION Reserves included herein are stated on a company interest basis (working interest plus royalty interests prior to deduction of royalty burdens) unless noted otherwise in addition, certain reserves included herein are stated on a gross (working interest excluding royalty interests and burdens) and net (working interest plus royalty interest less royalty burdens) basis as defined in NI 51-101.  "Company interest" is not a term defined by NI 51-101 and as such the estimates of company interest reserves herein may not be comparable to estimates prepared in accordance with NI 51-101 or to other issuers' estimates of company interest reserves.At December 31, 2012 the Company's proved plus probable company interest reserves as evaluated by Sproule, using forecast prices and costs, were 104,258 mboe, an increase of 54.3% compared to 67,550 mboe at December 31, 2011.  By commodity type, natural gas made up 67% and oil and natural gas liquids 33% of total proved plus probable reserves.  At December 31, 2012, the Company's total proved company interest reserves were 55,490 mboe, an increase of 32.7% compared to 41,818 mboe at December 31, 2011 (calculated after taking into account 2012 production of 6,107 mboe).In addition to the information disclosed herein, more detailed information on the Company's reserves will be included in the Company's Annual Information Form.Reserves, at December 31, 2012, as evaluated by Sproule, are summarized below and in the following tables.Summary of Oil and Gas Company Interest Reserves1 (Gross + Royalties Receivable)Forecast Prices and Costs  As at Dec. 31, 2012As at Dec. 31, 2011  Natural Gas2Heavy OilLight andNatural GasTotalTotal    Medium OilLiquids    (mmcf)(mbbl)(mbbl)(mbbl)(mboe, 6:1)(mboe, 6:1)Proved       Developed producing91,900685,3373,79624,51819,336 Developed non-producing787-1322166438 Undeveloped121,9201135,1295,24430,80722,043Total proved214,60718110,4799,06255,49041,818Probable203,0772246,0738,62448,76725,732Proved plus probable, producing128,726927,5275,32534,39827,405Total proved plus probable417,68440516,55217,687104,25867,5501 "Company Interest" means Bellatrix's working interest (operated or non-operated) share before deduction of royalties but after including any royalty interests of Bellatrix. May not add due to rounding.2 Includes natural gas from coal bed methane and shale gas reserves.Summary of Oil and Gas Working Interest Reserves1 (Gross)Forecast Prices and Costs  As at Dec. 31, 2012As at Dec. 31, 2011  Natural Gas2Heavy OilLight andNatural GasTotalTotal    Medium OilLiquids    (mmcf)(mbbl)(mbbl)(mbbl)(mboe, 6:1)(mboe, 6:1)Proved       Developed producing91,664685,3373,78724,46819,302 Developed non-producing787-1322166438 Undeveloped120,8981135,1195,20030,58122,021Total proved213,34818110,4689,00855,21541,761Probable201,9622246,0588,57648,51925,674Proved plus probable, producing128,441937,5265,31234,39627,318Total proved plus probable415,31040516,52617,584103,73467,4351 "Working Interest" means Bellatrix's working interest (operated or non-operated) share before deduction of royalties.  Also referred to as "Gross" reserves under NI 51-101.  May not add due to rounding.2 Includes natural gas from coal bed methane and shale gas reserves. Summary of Oil and Gas Net Reserves1 (Net)Forecast Prices and Costs  As at Dec. 31, 2012As at Dec. 31, 2011  Natural Gas2Heavy OilLight andNatural GasTotalTotal    Medium OilLiquids    (mmcf)(mbbl)(mbbl)(mbbl)(mboe, 6:1)(mboe, 6:1)Proved       Developed producing72,206524,1592,25318,52614,906 Developed non-producing641-912128337 Undeveloped93,809864,2873,52723,53616,279Total proved166,6561388,4555,79342,18931,522Probable153,5891694,8285,47736,09518,970Proved plus probable, producing100,625715,8003,11525,80620,792Total proved plus probable320,24430713,86211,27078,28450,4921 "Net" means Bellatrix's working interest (operated or non-operated) share after deduction of royalty obligations, plus Bellatrix's royalty interests in reserves. May not add due to rounding.2 Includes natural gas from coal bed methane and shale gas reserves.COMPANY INTEREST1 (Gross + Royalties Receivable) RESERVES RECONCILIATION Light andMediumCrude Oil(mbbl)Heavy CrudeOil (mbbl)Total CrudeOil (mbbl)NGLs (mbbl)ConventionalNatural Gas(mmcf)2OilEquivalent(mboe)PROVED PRODUCING      Opening Balance4,380              651          5,031          2,414        71,351        19,336 Extensions646-6461,05924,1005,721 Infill Drilling------ Improved Recovery------ Technical Revisions1,376231,3991,15819,4165,793 Discoveries---21,945327 Acquisitions99-991242,806691 Dispositions-(504)(504)-(20)(507) Economic Factors(81)-(81)(53)(3,611)(736) Production(1,083)(103)(1,186)(907)(24,087)(6,107)Closing Balance5,337685,4053,79691,90024,518TOTAL PROVED      Opening Balance          8,840              861          9,701          5,718      158,398        41,818 Extensions          1,198                   -          1,198          2,338        54,592        12,634 Infill Drilling              674                   -              674              200          4,442          1,614 Improved Recovery   -                   -                   -                   -                   -                   - Technical Revisions              672(73)              599          1,363        17,241          4,835 Discoveries                   -                   -                   -                   2          1,945              327 Acquisitions              283                   -              283              426          6,799          1,842 Dispositions                   -(504)(504)                   -            (501)            (587) Economic Factors            (105)                   -            (105)              (77)        (4,222)            (886) Production        (1,083)(103)        (1,186)            (907)(24,087)                (6,107)Closing Balance        10,479              181        10,660          9,062      214,607        55,490PROBABLE      Opening Balance          5,703              382          6,085          3,677        95,820        25,734 Extensions          1,055                   -          1,055          3,779        87,004        19,335 Infill Drilling              713                   -              713              148          3,079          1,374 Improved Recovery                   -                   -                   -                   -                   -                   - Technical Revisions        (1,729)                60        (1,669)              551          3,980            (455) Discoveries                   -                   -                   -                   -              421                71 Acquisitions              283                   -              283              503        14,107          3,137 Dispositions                   -            (218)            (218)                   -            (155)            (244) Economic Factors                47                   -                47              (33)        (1,179)            (183) Production                   -                   -                   -                   -                   -                   -Closing Balance          6,073              224          6,297          8,624      203,077        48,767PROVED PLUS PROBABLE     Opening Balance        14,543          1,242        15,785          9,395      254,218        67,550 Extensions          2,253                   -          2,253          6,117      141,596        31,969 Infill Drilling          1,388                   -          1,388              348          7,521          2,989 Improved Recovery    -                   -                   -                   -                   -                   - Technical Revisions  (1,057)              (13)        (1,070)          1,914        21,222          4,380 Discoveries    -                   -                   -                   3          2,366              397 Acquisitions  566                   -              566              929        20,906          4,979 Dispositions    -            (722)            (722)                   -            (656)            (831) Economic Factors(58)                   -              (58)            (111)        (5,401)        (1,069) Production        (1,083)            (103)        (1,184)            (907)      (24,087)        (6,107)Closing Balance        16,552              405        16,957        17,687      417,684      104,2581 "Company Interest" means Bellatrix working interest (operated or non-operated) share before deduction of royalties but i ncluding any royalty interests of Bellatrix.  Based on forecast prices and costs.  May not add due to rounding.2 Company coal bed methane and shale gas reserves have been included in Natural Gas.  Coal bed methane reserves had been reconciled separately in previous reserve press releases; however, coal bed methane and shale gas reserves represent an immaterial portion of the Company's Natural Gas reserves.WORKING INTEREST1 (Gross) RESERVES RECONCILIATION Light andMediumCrude Oil(mbbl)Heavy CrudeOil (mbbl)Total CrudeOil (mbbl)NGLs (mbbl)ConventionalNatural Gas(mmcf)2OilEquivalent(mboe)PROVED PRODUCING      Opening Balance          4,380              646          5,026          2,409        71,208        19,302 Extensions646-6461,05924,1005,721 Infill Drilling------ Improved Recovery------ Technical Revisions1,374231,3961,15219,3005,765 Discoveries---21,945327 Acquisitions99-991242,806691 Dispositions-(499)(499)-(19)(502) Economic Factors(81)-(81)(54)(3,623)(738) Production(1,082)(103)(1,185)(905)(24,052)(6,098)Closing Balance5,337685,4053,78791,66424,469TOTAL PROVED      Opening Balance          8,840              856          9,696          5,709      158,144        41,761 Extensions          1,198                   -          1,198          2,323        54,226        12,558 Infill Drilling              663                   -              663              199          4,433          1,601 Improved Recovery                   -                   -                   -                   -                   -                   - Technical Revisions              670              (73)              597          1,457        16,574          4,906 Discoveries                   -                   -                   -                   2          1,945              327 Acquisitions              283                   -              283              302          6,799          1,718 Dispositions                   -            (499)            (499)                   -            (499)            (582) Economic Factors            (105)                -            (105)              (77)        (4,222)            (886) Production        (1,082)            (103)        (1,185)            (905)      (24,052)        (6,098)Closing Balance        10,468              181        10,649          9,008      213,348        55,215PROBABLE      Opening Balance          5,703              375          6,079          3,668        95,561        25,674 Extensions          1,055                   -          1,055          3,753        86,398        19,207 Infill Drilling              699                   -              699              147          3,069          1,357 Improved Recovery                   -                   -                   -                   -                   -                   - Technical Revisions        (1,729)                61        (1,669)              415          3,739            (631) Discoveries                   -                   -                   -                   -              421                71 Acquisitions              283                   -              283              627        14,107          3,261 Dispositions                   -            (212)            (212)                   -            (154)            (238) Economic Factors                47                   -                47              (33)          (1179)            (183) Production                   -                   -                   -                   -                   -                   -Closing Balance          6,058              224          6,282          8,576      201,962        48,519PROVED PLUS PROBABLE     Opening Balance        14,543          1,231        15,774          9,377      253,705        67,435 Extensions          2,253                   -          2,253          6,075      140,624        31,765 Infill Drilling          1,362                   -          1,362              346          7,502          2,959 Improved Recovery                   -                   -                   -                   -                   -                   - Technical Revisions        (1,059)              (13)        (1,073)          1,871        20,315          4,185 Discoveries                   -                   -                   -                   3          2,366              397 Acquisitions              566                   -              566              929        20,906          4,979 Dispositions                   -            (710)            (710)                   -            (653)            (819) Economic Factors              (57)                   -              (57)            (111)        (5,401)        (1,068) Production        (1,082)            (103)        (1,185)            (905)      (24,052)        (6,098)Closing Balance        16,526              405        16,931        17,584      415,310      103,7341 "Working Interest" means Bellatrix working interest (operated or non-operated) share before deduction of royalties and without including any royalty interest of Bellatrix.  Also referred to as "Gross" reserves under NI 51-101.  May not add due to rounding.2 Company coal bed methane and shale gas reserves have been included in Natural Gas.  Coal bed methane reserves had been reconciled separately in previous reserve press releases; however, coal bed methane and shale gas reserves represent an immaterial portion of the Company's Natural Gas reserves.TAX POOLSAt December 31, 2012, the Company had approximately $584 million in tax pools available for deduction against future income as follows:     ($000s) Rate %2012     (unaudited)2011Canadian exploration expenses10045,90047,600Canadian development expenses30369,300326,900Canadian oil and gas property expenses1040,40025,100Foreign resource expenses10800800Attributed Canadian Royalty Income(Alberta) 10016,10016,100Undepreciated capital cost(1)6-5598,00083,100Non capital losses  (expire through 2027)10010,00010,000Financing  costs20 S.L3,3004,700Total Tax Pools 583,800513,300(1) Approximately $91 million of undepreciated capital cost pools are class 41, which is claimed at a 25% rate.FUTURE DEVELOPMENT COSTS USING FORECAST PRICES AND COSTSAt year-end, 2012, Sproule had evaluated certain future development opportunities on Company lands including 161 gross (112.7 net) future undrilled Cardium horizontal locations and 56 gross (23.3 net) evaluated future undrilled Notikewin/Falher horizontal locations.  Of the 161 Cardium locations, 104 were assigned proved and probable reserves, with 57 assigned probable reserves only.  Of the 56 Notikewin/Falher locations, 41 were assigned proved and probable reserves, with the remaining 15 assigned probable reserves only.For purposes of assigning net present value of future revenue, future development locations were committed as detailed in the following table.  On the basis of current cash flow projections, the schedule, and resulting NPV, can be considered conservative, as the future development inventory represents only approximately two years of reinvested cash flow.($000's)Proved Future Development CostsProved plus Probable Future Development Costs2013201420152016 and subsequent109,439126,29274,03217,642157,773172,707141,06053,097Undiscounted total327,407524,638Discounted @ 10%/yr288,291452,101RESERVE REPORT COMMODITY PRICINGThe following is a summary of the Consultants' Average Forecast Prices as at January 1, 2013: OIL     YearForecastWTICushing Oklahoma($US/Bbl) Edmonton Par Price40° API ($Cdn/Bbl) Western Canada Select 20.5 API ($Cdn/Bbl)  NATURAL GAS AECO Price ($Cdn/MMBTU)NATURAL GAS LIQUIDS at Edmonton3($Cdn/Bbl) INFLATION RATES1%/Year EXCHANGE RATE2($US/$Cdn)201390.7185.6869.733.3594.891.831.0003201491.6490.6175.363.8096.571.831.0003201592.3091.6075.714.1895.971.831.0003201696.1795.4880.234.71100.081.831.0003201797.2996.5980.835.12101.221.831.0003201898.4497.7181.445.36102.411.831.0003201999.9499.2182.495.45104.001.831.00032020101.76101.0383.945.57105.881.831.00032021103.61102.8885.415.67107.821.831.00032022105.54104.8186.915.77109.851.831.00032023107.46106.6988.435.87111.821.831.00032024109.43108.6589.975.99113.851.831.00032025111.43110.6491.546.09115.941.831.00032026113.48112.6993.156.19118.091.831.00032027115.59114.7694.786.31120.261.831.0003Thereafter+ 1.8%/yr+ 1.8%/yr+ 1.8%/yr+ 1.8%/yr+ 1.8%/yr  1 Inflation rates for forecasting prices and costs2 Exchange rates used to generate the benchmark reference prices in this table3   Natural Gas Liquids is represented by the pentanes plus priceWeighted average historical prices realized by Bellatrix (before commodity price risk management contracts) for the year ended December 31, 2012, were $2.62/mcf for natural gas, $86.47/bbl for light, medium gravity crude oil and condensate, $68.51/bbl for heavy oil and $38.88/bbl for natural gas liquids (excluding condensate).RESERVES COMMITTEEBellatrix has a reserves committee, comprised of independent board members, that reviews the qualifications and appointment of the independent reserve evaluators. The committee also reviews the procedures for providing information to the evaluators.  All booked reserves are based upon annual evaluations by the independent qualified reserve evaluators conducted in accordance with the COGE (Canadian Oil and Gas Evaluation) Handbook and NI 51-101. The evaluations are conducted using all available geological and engineering data. The reserves committee has reviewed the reserves information and approved the reserve report.LAND As at December 31, 2012, Bellatrix had over 206,638 net undeveloped acres in Alberta, British Columbia and Saskatchewan.Land Statistics   20122011Average working interest   Developed57%57% Undeveloped66%63%Total61%60%   Land Holdings1   20122011 GrossNetGrossNetDeveloped    British Columbia9,7522,69219,8507,315  Alberta373,705    211,967    370,653    209,786  Saskatchewan13,32712,72013,32712,720  Total396,784227,380403,830229,821Undeveloped    British Columbia107,70047,521143,96860,590  Alberta194,158148,815198,777152,363  Saskatchewan10,30210,30211,60611,606  Total312,160206,638354,351224,559Developed and Undeveloped    British Columbia117,45250,213163,81867,905  Alberta567,864360,782569,429362,149  Saskatchewan23,62823,02224,93424,326Total708,944434,017758,181454,3801 May not add due to rounding    OPERATIONS OUTLOOKBellatrix continues to focus on growth by development of its large inventory of Cardium and Notikewin/Falher assets geological prospects. The Company also continues to focus on adding Cardium and Notikewin prospective lands.Bellatrix has entered into a joint venture agreement with a Seoul, Korea based company ("JV Partner"), effective January 2013, to accelerate development of Bellatrix's extensive undeveloped Cardium land holdings in west-central Alberta.  As a result of the Joint Venture, Bellatrix's net capital expenditure plan for 2013 is expected to increase from the previously announced $180 million level to between $230 and $240 million, not including JV Partner capital. Based on the timing of proposed expenditures, downtime from anticipated plant turnarounds, completion of anticipated infrastructure and normal production declines, execution of the increased 2013 capital expenditure plan is anticipated to provide average daily production of 24,000 to 25,000 boe/d. The Company is anticipating a 2013 exit rate of 30,000 to 31,000 boe/d. The Company has budgeted a capital program between $230 and $240 million funded from the Company's cash flows and to the extent necessary, bank indebtedness, based on the current economic conditions and Bellatrix's operating forecast for 2013 and assuming the closing of the joint venture transaction with the JV Partner.  A total capital program of $365 million is expected including the capital expected to be invested by the JV Partner.  The capital budget is expected to be directed primarily towards horizontal drilling and completions activities in the Cardium and Notikewin/Falher areas.The Company has developed an inventory of 692 net remaining Cardium locations and 401 net Notikewin/Falher locations representing a net capital development opportunity of $4.34 billion based on current costs.The Company has identified $8.22 billion in potential development including all identified prospects and based on current costs representing over 40 years of drilling inventory based on current annual cash flow.As at December 31, 2012, Bellatrix has approximately 206,638 net undeveloped acres and, including all opportunities, has in excess of 1,700 net exploitation drilling opportunities identified.As at December 31, 2012, approximately $87 million or 40% was undrawn under the existing $220 million credit facilities and is available to fund Bellatrix's ongoing capital spending and operational requirements.COMMODITY RISK MANAGEMENT CONTRACTSBellatrix has the following crude oil and natural gas commodity price risk management contracts in place for 2013.  The conversion of $/GJ to $/mcf is based on an average corporate heat content rate of 40.8Mj/m3.ProductTerm VolumeAverage PriceCrude Oil1Jan. 1, 2013 to Dec. 31, 20131,500 bbls/d$94.50 CDN/bblNatural GasFeb. 1, 2013 to Mar. 31, 20138.7 mmcf/d$3.51 CDN/mcfNatural GasApr. 1, 2013 to Oct. 31, 201347.8 mmcf/d  $3.52 CDN/mcfNatural GasNov. 1, 2013 to Dec. 31, 201321.7 mmcf/d$3.51 CDN/mcfNatural GasJan. 1, 2014 to Jun. 30, 201413.0 mmcf/d$3.51 CDN/mcf1 A call has been placed on 3,000 bbls/d at $110 US/bbl for the year 2013 and at $105US/bbl for the calendar year 2014. Based on exit rate of December 2012 production volumes of approximately 19,500 boe/d annualized for 2013, Bellatrix has put in price protection on approximately 53% of 2013 production volumes, 27% for first and second quarter and 15% for third and fourth quarter 2014 production volumes.An updated corporate presentation is available on www.bellatrixexploration.com.Bellatrix Exploration Ltd. is a growth oriented exploration and production company based in Calgary, Alberta, Canada.READER ADVISORIES: (to be updated) CONVERSION:  The term barrels of oil equivalent ("boe") may be misleading, particularly if used in isolation. A boe conversion ratio of six thousand cubic feet of natural gas to one barrel of oil equivalent (6 mcf/bbl) is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead.  All boe conversions in this report are derived from converting gas to oil in the ratio of six thousand cubic feet of gas to one barrel of oil. Given that the value ratio based on the current price of crude oil as compared to natural gas is significantly different from the energy equivalency of 6:1, utilizing a conversion on a 6:1 basis may be misleading as an indication of value.UNAUDITED 2012 FINANCIAL INFORMATION: As Bellatrix  plans to announce its audited 2012 financial results on or about March 7, 2013, certain financial information for the year ended December 31, 2012 disclosed herein, or used in various calculations herein, is based on unaudited information and has been utilized by Bellatrix in this release to facilitate the discussion with respect to the performance of our capital program. Readers are advised that these financial estimates are subject to audit and may be subject to change as a result, and such changes could be material.NON-GAAP MEASURES:  The press release section contains the term "funds flow from operations" which should not be considered an alternative to, or more meaningful than cash flow from operating activities as determined in accordance with Canadian generally accepted accounting principles ("GAAP") as an indicator of the Company's performance. Therefore reference to diluted funds flow from operations or funds flow from operations per share may not be comparable with the calculation of similar measures for other entities. Management uses funds flow from operations to analyze operating performance and leverage and considers funds flow from operations to be a key measure as it demonstrates the Company's ability to generate the cash necessary to fund future capital investments and to repay debt.  The reconciliation between cash flow from operating activities and funds flow from operations can be found in the document.  Funds flow from operations per share is calculated using the weighted average number of common shares for the period.Management believes that this measure is a useful supplemental measure of cash flow from operations.  Readers are cautioned, however, that these measures should not be construed as an alternative to cash flow from operations determined in accordance with GAAP as a measure of performance. Bellatrix's method of calculating these measures may differ from other entities, and accordingly, may not be comparable to measures used by other trusts or companies.INITIAL PRODUCTION RATES: Any references in this press release to initial production rates and/or 7, 15 and 30 day production rates are useful in confirming the presence of hydrocarbons, however, such rates are not determinative of the rates at which such wells will continue production and decline thereafter. Additionally, such rates may also include recovered "load oil" fluids used in well completion stimulation. While encouraging, readers are cautioned not to place reliance on such rates in calculating the aggregate production for Bellatrix.FORWARD LOOKING STATEMENTS:  Statements in this document may contain forward-looking information including management's assessment of future plans and operations, expected 2013 average production and exit production, reserve estimates, anticipated additional drilling locations, the total future capital associated with development of drilling locations and reserves, 2013 capital expenditures and expected amount of total program including capital to be invested by the JV Partner, expected closing of joint venture transaction, timing of completion and testing of wells and timing of release of 2012 financial results. The reader is cautioned that assumptions used in the preparation of such information may prove to be incorrect. Events or circumstances may cause actual results to differ materially from those predicted, a result of numerous known and unknown risks, uncertainties, and other factors, many of which are beyond the control of the Company. These risks include, but are not limited to: the risks associated with the oil and gas industry; commodity prices; risks that the joint venture transaction will close when expected or at all, and exchange rate changes. Industry related risks could include, but are not limited to: operational risks in exploration; development and production; delays or changes in plans; risks associated to the uncertainty of reserve estimates; health and safety risks, and; the uncertainty of estimates and projections of production, costs and expenses. The recovery and reserve estimates of Bellatrix's reserves provided herein are estimates only and there is no guarantee that the estimated reserves will be recovered. In addition, forward-looking statements or information are based on a number of factors and assumptions which have been used to develop such statements and information but which may prove to be incorrect. Although the Company believes that the expectations reflected in such forward-looking statements or information are reasonable, undue reliance should not be placed on forward-looking statements because the Company can give no assurance that such expectations will prove to be correct. In addition to other factors and assumptions which may be identified herein, assumptions have been made regarding, among other things: the impact of increasing competition; the general stability of the economic and political environment in which the Company  operates; the timely receipt of any required regulatory approvals; the ability of the Company  to obtain qualified staff, equipment and services in a timely and cost efficient manner; drilling results; the ability of the operator of the projects which the Company  has an interest in operating the field in a safe, efficient and effective manner; the ability of the Company  to obtain financing on acceptable terms; that the joint venture transaction will close when expected and on the terms expected; field production rates and decline rates; the ability to replace and expand oil and natural gas reserves through acquisition, development of exploration; the timing and costs of pipeline, storage and facility construction and expansion and the ability of the Company  to secure adequate product transportation; future commodity prices; currency, exchange and interest rates; the regulatory framework regarding royalties, taxes and environmental matters in the jurisdictions in which the Company  operates; and the ability of the Company  to successfully market its oil and natural gas products. Readers are cautioned that the foregoing lists of factors and assumptions are not exhaustive. Additional information on these and other factors that could affect the Company's operations and financial results are included in reports on file with Canadian securities regulatory authorities and may be accessed through the SEDAR website (www.sedar.com), at the Company's website (www.bellatrixexploration.com.). Furthermore, the forward-looking statements contained in this news release are made as at the date of this news release and the Company does not undertake any obligation to update publicly or to revise any of the included forward-looking statements, whether as a result of new information, future events or otherwise, except as may be required by applicable securities laws.  SOURCE: Bellatrix Exploration Ltd.For further information: BELLATRIX EXPLORATION LTD.  Raymond G. Smith, P.Eng.  President & CEO  (403) 750-2420  Edward J. Brown, CA Vice President, Finance & CFO  (403) 750-2655  Brent A. Eshleman P.Eng. Executive Vice President (403) 750-5566 Troy Winsor Investor Relations (800) 663-8072