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Bellatrix announces growth to 250 million boe in proved plus probable reserves establishing a 2P net asset value of $9.01 per share

TSX, NYSE: BXE

CALGARY, March 9, 2015 /PRNewswire/ - Bellatrix Exploration Ltd. ("Bellatrix" or the "Company") (TSX, NYSE: BXE) is pleased to announce its 2014 year-end reserves information.  Reserves at December 31, 2014 were independently evaluated 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").

2014 marked another successful and profitable growth year for Bellatrix.  The Company delivered a 100% success rate through the drill bit, anchoring another strong year of reserves growth as punctuated by the following achievements:

  • Bellatrix benefitted from its largest capital program in the Company's history which provided 18% growth in Proved plus Probable ("2P") reserves to a total of 250 million boe with a 10% NPVBT of $2.1 billion at December 31, 2014.  The NPVBT value was relatively unchanged from year end 2013 despite a material contraction in average near term (2 year) natural gas and oil price forecasts used by independent reserve evaluators.
  • Proved ("1P") reserves grew 30% year over year to 161 million boe.
  • Proved Developed Producing ("PDP") reserves grew 37% to 74 million boe with a 10% NPVBT value of $932 million, equivalent to $4.85 per basic share. 
  • As at December 31, 2014 2P reserves were comprised of 80 million barrels of oil and natural gas liquids as well as 1.0 trillion cubic feet of natural gas, with a 32% liquids weighting on a boe basis.
  • 2P reserves added at a finding, development and acquisition ("FD&A") cost of $12.13/boe, excluding the change in future development capital ("FDC") requirements.  Including the change in FDC requirements, FD&A totaled $13.22/boe.  Excluding approximately $36 million invested in the Bellatrix deep-cut plant during 2014, 2P FD&A costs averaged $11.48/boe and $12.58/boe excluding and including the change in FDC respectively.
  • Excluding the change in FDC, Bellatrix delivered a 2P Recycle Ratio of 1.82x on total 2014 capital, and 1.92x excluding $36 million spent directly on its deep-cut gas plant project.
  • Bellatrix's December 31, 2014 net asset value of $1.7 billion, equivalent to $9.01/share using a 10% per year discount to future net revenue adjusted for year-end net debt, seismic, and land value.
  • The Company replaced 369% of total production in 2014.
  • The Company's calculated 1P reserve life index improved by 16% to 10.6 years and is 13.3 years based on 2P reserves.
  • Annual production increased by 74% in 2014 to 13.9 million boe from 8.0 million boe in 2013.

 

A conference call to discuss Bellatrix's annual financial and reserves results will be held on March 12, 2015 at 9:00 am MDT/11:00 am EDT. To participate, please call toll-free 1-888-231-8191 or 647-427-7450. The conference call will also be recorded and available by calling 1-855-859-2056 or 403-451-9481 and entering passcode 94534280#.

2014 ACHIEVEMENTS







Twelve months ended December,




2014

2013


% Change

Reserves (Company Interest (1), mboe)






Proved Developed Producing

74,181

54,078


+37%


Total Proved

161,448

124,154


+30%



Proved Undrilled/Total Proved

54%

56%




Total Proved and Probable

250,098

211,536


+18%



Probable/Total Proved and Probable

35%

41%








Net Present Value of Reserves (Before Tax, 10% Discount Rate)






Proved Developed Producing ($MM)

$932

$879


+6%


Total Proved ($MM)

$1,412

$1,433


-1%


Proved and Probable ($MM)

$2,116

$2,090


+1%






Net Asset Value






Proved and Probable ($MM) (2)

$1,729

$1,949




Proved and Probable Net Asset Value, per basic share

$9.01

$11.40








FD&A costs






1P, including FDC ($/boe)

$13.80

$13.76




2P, including FDC ($/boe)

$13.22

$9.67




1P, including FDC ($/boe) excluding deep-cut gas plant capital

$13.14





2P, including FDC ($/boe) excluding deep-cut gas plant capital

$12.58





3 year average 2P, including FDC ($/boe)

$10.05

$9.01








Selected Key Operating Statistics






Annual Average Sales Volumes (boe/d)

38,065

21,829


+74%


Q4 Average Sales Volumes (boe/d)

42,945

23,968


+79%


Operating netback ($/boe) (3)

$22.04

$20.99


+5%


Funds Flow From Operations ($ millions) (4) (unaudited)

$270.8

$143.5


+89%


Funds Flow per basic share (unaudited)

$1.48

$1.27


+17%






Reserve Life Index






Proved

  10.6 yrs.

  9.1 yrs.


+16%


Proved and Probable

  13.3 yrs.

13.7 yrs.


-3%

Recycle Ratios (3)






1P, excluding FDC

  1.76 x

  1.88 x




2P, excluding FDC

  1.82 x

2.90 x




1P, excluding FDC and deep-cut gas plant capital

  1.86 x





2P, excluding FDC and deep-cut gas plant capital

  1.92 x









Evaluated Future Horizontal Drilling Locations






Gross Cardium

281





Net Cardium

206.6





Gross Mannville

185





Net Mannville

95.2




(1)

"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) 

Proved plus Probable net asset value incorporates 2P NPV10 (Before tax) value and adjusts for year-end net debt, seismic, and
land value.

(3)

Operating netback is not a recognized term under Canadian generally accepted accounting principals ("GAAP") and is calculated
by deducting transportation, royalties and operating costs from revenue. Operating netback includes impact of commodity price
risk contracts.  See "Non-GAAP Measures".

(4) 

Funds flow from operations is not a recognized term under Canadian generally accepted accounting principles. See "Non-GAAP
Measures".

 

SELECT 2014 OPERATING RESULTS

To assist in interpretation of the Company's reserves and key achievements, Bellatrix releases select 2014 unaudited operating results ahead of full year-end 2014 financial results including data on capital expenditures, cash flow from operating activities, and drilling results.

CAPITAL EXPENDITURES








Years ended December 31,

($000s)



2014

(unaudited)



2013

Lease acquisitions and retention



16,701



11,190

Geological and geophysical



1,601



140

Drilling and completion costs



298,313



211,912

Facilities and equipment



220,773



57,767

Property transfers – cash



(32,921)



-

Capital – exploration and development (1)  



504,467



281,009

Capital – corporate assets (2)



11,163



9,270

Property acquisitions



176,428



13,386


Total capital expenditures – cash



692,058



303,665

Property dispositions – cash



(9,809)



(70,942)


Total net capital expenditures – cash



682,249



232,723

Corporate acquisition  – non cash



-



595,891

Property acquisitions – non cash



68,616



-

Other – non cash (3)



20,000



12,187


Total - non – cash



88,616



608,078

Total capital expenditures – net



770,865



840,801








(1)

Excludes capitalized costs related to decommissioning liabilities expenditures incurred during the period.

(2)

Capital – corporate assets includes office leasehold improvements, furniture, fixtures and equipment
before recoveries realized from landlord lease inducements.

(3)

Other includes non-cash adjustments for the current period's decommissioning liabilities and share based
compensation.

 

The $771 million capital program for the year ended December 31, 2014 was financed from funds flow from operations, a common share offering, and bank debt.

RECONCILIATION OF CASH FLOW FROM OPERATING ACTIVITIES AND FUNDS FLOW FROM OPERATIONS








Years ended December 31,

($000s)



2014

(unaudited)



2013

Cash flow from operating activities



294,828



128,458

Decommissioning costs incurred



1,743



1,057

Transaction costs



-



5,344

Change in non-cash working capital



(25,818)



8,600

Funds flow from operations (1)



270,753



143,459

(1) 

Funds flow from operations is not a recognized term under Canadian generally accepted accounting principles.
See "Non-GAAP Measures".

 

Bellatrix generated funds flow from operations of $270.8 million ($1.48 per basic share and $1.46 per diluted share) for the year ended December 31, 2014, an increase of 89% from $143.5 million ($1.27 per basic share and $1.24 per diluted share) generated in 2013.  Bellatrix's cash flow from operating activities of $294.8 million ($1.61 per basic share and $1.59 per diluted share) for the year ended December 31, 2014 increased by 130% from the $128.5 million ($1.14 per basic share and $1.11 per diluted share) generated in 2013.  The increase in funds flow from operations between 2013 and 2014 was principally due to an increase of 74% in production volumes and higher realized natural gas prices, partially offset by reduced NGL prices, a net realized loss on commodity contracts in 2014 compared to a net realized gain on commodity contracts in 2013, and increased general and administrative, production, transportation, royalty, and finance expenses related to the increased operational activity.

2014 RESERVES

Bellatrix 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, 2014. 

Highlights of Bellatrix's December 31, 2014 reserves report include:

  • 250 million boe total company interest Proved and Probable reserves, and 161 million boe total company interest Proved reserves as at December 31, 2014, representing 18% and 30% year over year growth respectively.
  • $2.1 billion net present value of future net revenue of Proved plus Probable reserves before tax at 10% discount rate up 1% from year end December 31, 2013 despite an average 10% to 20% contraction in near term (2 year) forecast natural gas prices by reserve evaluators.
  • Net asset value, as at December 31, 2014 is $9.01 per basic share outstanding based on the Sproule evaluation of Proved and Probable reserves at a 10% discount rate.
  • 369% replacement of production with 2P company interest reserve additions in year ended 2014. 
  • $13.80/boe FD&A for proved reserves including changes to future development capital and $12.53/boe FD&A for 1P reserves excluding changes to FDC for the year ended 2014.
  • $13.22/boe FD&A for total proved and probable reserves including changes to future development capital and FD&A of $12.13/boe for total 2P reserves excluding changes to FDC for the year ended 2014.
  • $10.05/boe 3-year 2P FD&A including FDC.
  • 13.3 year reserve life index on a total working interest Proved plus Probable basis at December 31, 2014 and increased the Company's Proved reserve life index to 10.6 years, up 16% from 9.1 years at December 31, 2013.
  • 281 gross (206.6 net) Cardium evaluated future undrilled horizontal locations.
  • 185 gross (95.2 net) Mannville evaluated future undrilled horizontal locations.

 










2014 Reserves


2013
Reserves





Oil & Liquids


Natural Gas


Total


Total


Variance



(mbbl)


(mmcf)


(mboe)


(mboe)


%

Proved


51,637


658,863


161,448


124,154


+30%

Probable


28,750


359,404


88,650


87,382


+1%

Proved Plus Probable  


80,387


1,018,267


250,098


211,536


+18%

 

NET ASSET VALUE – PROVED PLUS PROBABLE

The following table of net asset value, as at December 31, 2014, 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 Probable Reserves (1)


4,753,295


3,020,462


2,115,605


1,574,039


1,219,481

Undeveloped Lands (2)


225,276


225,276


225,276


225,276


225,276

Value of Seismic (3)


26,068


26,068


26,068


26,068


26,068

Net Debt (4)


(637,726)


(637,726)


(637,726)


(637,726)


(637,726)

Net Asset Value (5)


4,366,913


2,634,080


1,729,223


1,187,657


833,099












Per Basic Common Share (5)(6)


$22.75


$13.72


$9.01


$6.19


$4.34

(1)

As evaluated by Sproule as at December 31, 2014 based on forecast prices and costs before income tax.

(2)

As estimated by Bellatrix as at December 31, 2014 based on 385,397 net acres of undeveloped land at an average price of
$584.53 per acre

(3)

Based on 26.1% of $99.8 million replacement value based on seismic costs to buy data at an average of $1,500/km for 2d
and $14,500/km2 for 3D.

(4)

The Company's calculation of Net Debt as at December 31, 2014, includes long-term debt and the net working capital
deficiency (excess). The net working capital deficiency (excess) excludes the current portions of: finance lease obligation,
deferred lease inducements and commodity contract liability and asset. See "Additional GAAP Measures".

(5)

Certain of the information used in the foregoing calculation, including net debt and number of common shares outstanding,
is based on unaudited financial information.

(6)

Based on 191.95 million common shares outstanding as at December 31, 2014

           

NET PRESENT VALUE OF FUTURE NET REVENUE ("NPV")

The forecast prices used in Sproule's reserve report effective December 31, 2014 (the "Sproule Report") were an average of the forecast prices published by Sproule, GLJ Petroleum Consultants Ltd. and McDaniel & Associates Consultants Ltd., as at January 1, 2015 (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, estimated royalties payable, estimated operating 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 $863 million ($742 million discounted at 10%) and $1,336 million ($1,152 million discounted at 10%) for the total proved and probable reserves. The change in 2014 net total future capital over the life of the reserves associated with the proved reserves is $76 million ($67 million discounted at 10%) and $51 million ($55 million discounted at 10%) for the total proved and probable reserves.  Calculated changes in net future capital exclude future capital from acquired properties.

SUMMARY OF NPV BEFORE INCOME TAXES (1), (2)












As at December 31, 2014


0%


5%


10%


15%


20%

Proved












Developed producing


1,562,159


1,162,721


932,046


782,872


678,792


Developed non-producing


27,463


21,785


17,872


15,064


12,976


Undeveloped


1,346,355


768,248


461,602


279,377


162,344

Total proved


2,935,976


1,952,754


1,411,520


1,077,313


854,112

Probable


1,817,319


1,067,708


704,085


496,725


365,370

Total proved plus probable


4,753,295


3,020,462


2,115,605


1,574,039


1,219,481

(1)

Forecast Prices and Costs ($000s). Discounted at (%/year).

(2)

May not add due to rounding.

 

SUMMARY OF NPV AFTER INCOME TAXES (1), (2), (3)













As at  December 31, 2014


0%


5%


10%


15%


20%

Proved












Developed producing


1,562,159


1,162,721


932,046


782,872


678,792


Developed non-producing


27,463


21,785


17,872


15,064


12,976


Undeveloped


1,018,812


594,238


360,220


216,319


121,175

Total proved


2,608,434


1,778,744


1,310,138


1,014,255


812,943

Probable


1,362,632


796,728


521,876


365,112


265,818

Total proved plus probable


3,971,066


2,575,472


1,832,014


1,379,367


1,078,761

(1)

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.

 

FD&A COSTS (1), (2)


















2014



2013



2012



2012 – 2014 Avg.

PROVED PLUS PROBABLE FD&A COSTS













Excluding FDC













FD&A Costs, 2P ($/boe)














Exploration and development (3)



21.21



4.73



4.29



7.82


Acquisitions (excluding dispositions) (4)



5.45



9.70



4.21



8.02


Total (including acquisitions)



12.13



7.24



4.28



7.91


Total excluding plant capital



11.48










Including FDC (3)













FD&A Costs, 2P ($/boe)














Exploration and development



23.80



9.65



7.31



11.69


Acquisitions (excluding dispositions) (4)



5.45



9.70



4.21



8.02


Total (including acquisitions)



13.22



9.67



6.95



10.05


Total excluding plant capital



12.58























PROVED FD&A COSTS













Excluding FDC













FD&A Costs, 1P ($/boe)














Exploration and development (3)



16.32



6.21



8.87



10.03


Acquisitions (excluding dispositions) (4)



7.53



18.04



12.20



13.61


Total (including acquisitions)



12.53



11.17



9.16



11.39


Total excluding plant capital



11.86










Including FDC (3)













FD&A Costs, 1P ($/boe)














Exploration and development



18.56



10.67



11.73



13.45


Acquisitions (excluding dispositions) (4)



7.53



18.04



22.20



13.61


Total (including acquisitions)



13.80



13.76



11.77



13.51


Total excluding plant capital



13.14























PROVED DEVELOPED PRODUCING FD&A COSTS













FD&A Costs, PDP ($/boe)














Exploration and development (3)



17.06











Acquisitions (excluding dispositions) (4)



23.81











Total (including acquisitions)



18.42











Total excluding plant capital



17.43










(1)

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.

(3)

The aggregate of exploration and development costs incurred in the most recent 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.

(4)

FD&A is calculated using the announced purchase price for corporate acquisitions rather than the actual amount allocated to property, plant and equipment for accounting purposes.

 

RESERVE LIFE INDEX

Bellatrix'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 2014 is calculated by dividing reserves as at the effective date of the Sproule Report, December 31, 2014, by 2015 forecasted average production of 51,193 boe/d proved plus probable and 41,553 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.




















2014



2013



2012



2011



2010

Proved



10.6



9.1



8.6



8.0



7.2

Proved and Probable



13.3



13.7



12.4



10.0



11.2

 

RECYCLE RATIO (OPERATING NETBACK (1)/FD&A COST)









As at December 31, 2014



Proved



Proved and
Probable

Operating netback before commodity price risk management contracts ($/boe) (1) 
(unaudited)  



$24.34



$24.34

Recycle ratio (excluding change in FDC)



1.94 x



2.01 x

Recycle ratio (excluding change in FDC and deep-cut gas plant capital)



2.05 x



2.12 x








Operating netback after commodity price risk management contracts ($/boe) (1) 
(unaudited)  



$22.04



$22.04

Recycle ratio (excluding change in FDC)



1.76 x



1.82 x

Recycle ratio (excluding change in FDC and deep-cut gas plant capital)



1.86 x



1.92 x

(1)

Operating netback is calculated by deducting transportation, royalties and operating costs from revenue. (See Non-GAAP Measures)

 

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. In 2014, the Company made significant investment in infrastructure of $221 million including $36 million directly on the Bellatrix O'Chiese Nees-Ohpawganu'ck deep-cut gas plant.  For this reason, recycle ratio information is included for both the total capital program and the exploration and development program excluding capital spent directly on the plant.

RESERVES RECONCILIATION

Reserves included herein are stated either on a company interest basis (working interest plus royalty interests prior to deduction of royalty burdens), a gross (working interest excluding royalty interests and burdens) or a 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, 2014 the Company's proved plus probable company interest reserves as evaluated by Sproule, using forecast prices and costs, were 250,098 mboe, an increase of 18% compared to 211,536 mboe at December 31, 2013; total proved company interest reserves were 161,448 mboe, an increase of 30% compared to 124,154 mboe at December 31, 2013.  By commodity type, natural gas made up 68% and oil and natural gas liquids 32% of total proved plus probable reserves.  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, 2014, as evaluated by Sproule, are summarized below and in the following tables.


Summary of Oil and Gas Company Interest Reserves (1) (Gross + Royalties Receivable)

Forecast Prices and Costs



As at Dec. 31, 2014


As at Dec. 31,
2013



Natural Gas (2)


Heavy Oil

Light and


Natural Gas


Total


Total






Medium Oil


Liquids







(mmcf)


(mbbl)

(mbbl)


(mbbl)


(mboe, 6:1)


(mboe, 6:1)

Proved













Developed producing


292,542


24

9,009


16,391


74,181


54,078


Developed non-producing


6,406


77

205


306


1,656


781


Undeveloped


359,915


109

7,867


17,649


85,611


69,295

Total proved


658,863


210

17,081


34,346


161,448


124,154

Probable


359,404


214

7,721


20,815


88,650


87,382

Total proved plus probable


1,018,267


424

24,802


55,162


250,098


211,536

(1)

"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. Coal bed methane and shale gas reserves represent an immaterial
portion of the Company's natural gas reserves.

 















Summary of Oil and Gas Working Interest Reserves (1) (Gross)

Forecast Prices and Costs



As at Dec. 31, 2014


As at Dec. 31,
2013



Natural Gas (2)


Heavy Oil


Light and


Natural Gas


Total


Total







Medium Oil


Liquids







(mmcf)


(mbbl)


(mbbl)


(mbbl)


(mboe, 6:1)


(mboe, 6:1)

Proved














Developed producing


291,764


24


9,009


16,356


74,016


54,037


Developed non-producing


6,373


77


204


304


1,647


780


Undeveloped


356,650


109


7,867


17,508


84,926


69,295

Total proved


654,787


210


17,079


34,168


160,589


124,111

Probable


357,626


214


7,721


20,738


88,277


87,372

Total proved plus probable


1,012,413


424


24,800


54,907


248,866


211,483

(1)

"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. Coal bed methane and shale gas reserves represent an immaterial
portion of the Company's natural gas reserves.

 



Summary of Oil and Gas Net Reserves (1) (Net)

Forecast Prices and Costs



As at Dec. 31, 2014


As at Dec. 31,
2013



Natural Gas (2)


Heavy Oil


Light and


Natural Gas


Total


Total







Medium Oil


Liquids







(mmcf)


(mbbl)


(mbbl)


(mbbl)


(mboe, 6:1)


(mboe, 6:1)

Proved














Developed producing


237,063


21


7,305


10,959


57,796


41,012


Developed non-producing


5,419


59


175


205


1,343


638


Undeveloped


296,978


81


6,525


12,850


68,953


55,436

Total proved


539,460


162


14,006


24,014


128,091


97,086

Probable


288,774


155


6,129


14,744


69,158


68,050

Total proved plus probable


828,234


317


20,135


38,758


197,249


165,136

(1)

"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. Coal bed methane and shale gas reserves represent an
immaterial portion of the Company's natural gas reserves.

 



COMPANY INTEREST (1) (Gross + Royalties Receivable) RESERVES RECONCILIATION
















Light and
Medium
Crude Oil
(mbbl)


Heavy
Crude Oil
(mbbl)


Total Crude
Oil (mbbl)


NGLs
(mbbl)


Conventional
Natural Gas
(mmcf) (2)


Oil
Equivalent
(mboe)

PROVED PRODUCING













Opening Balance (3)


9,396


104


9,500


11,932


195,873


54,078


Extensions


90


-


90


613


13,492


2,952


Infill Drilling


235


-


235


1,739


40,166


8,669


Improved Recovery


-


-


-


-


-


-


Technical Revisions


1,059


(54)


1,005


4,240


81,627


18,850


Discoveries


57


-


57


43


1,042


273


Acquisitions


57


-


58


1,539


35,677


7,544


Dispositions


(203)


-


(203)


(794)


(17,844)


(3,971)


Economic Factors


11


(1)


11


(90)


(1,438)


(320)


Production


(1,694)


(26)


(1,720)


(2,832)


(56,053)


(13,894)

Closing Balance (3)


9,009


24


9,033


16,391


292,542


74,181

TOTAL PROVED













Opening Balance


18,993


217


19,210


25,850


474,560


124,154


Extensions


483


-


483


1,300


28,437


6,523


Infill Drilling


750


-


750


2,680


60,824


13,567


Improved Recovery


-


-


-


-


-


-


Technical Revisions


(1,713)


19


(1,694)


4,544


67,272


14,062


Discoveries


57


-


57


43


1,042


273


Acquisitions


421


-


421


4,897


113,504


24,235


Dispositions


(203)


-


(203)


(794)


(17,844)


(3,970)


Economic Factors


(12)


(1)


(13)


(1,343)


(12,880)


(3,502)


Production


(1,694)


(26)


(1,720)


(2,832)


(56,053)


(13,894)

Closing Balance


17,081


210


17,291


34,346


658,863


161,448

PROBABLE













Opening Balance


11,568


265


11,833


21,197


326,113


87,382


Extensions


602


-


602


1,140


24,422


5,812


Infill Drilling


794


-


794


1,857


40,896


9,468


Improved Recovery


-


-


-


-


-


-


Technical Revisions


(5,120)


(51)


(5,171)


(3,634)


(66,727)


(19,926)


Discoveries


11


-


11


9


216


55


Acquisitions


173


-


173


1,845


42,773


9,148


Dispositions


(38)


-


(38)


(183)


(4,125)


(908)


Economic Factors


(269)


-


(269)


(1,417)


(4,164)


(2,379)


Production


-


-


-


-


-


-

Closing Balance


7,721


214


7,935


20,815


359,404


88,650

PROVED PLUS PROBABLE













Opening Balance


30,561


482


31,043


47,047


800,673


211,536


Extensions


1,085


-


1,084


2,440


52,860


12,335


Infill Drilling


1,544


-


1,544


4,537


101,720


23,034


Improved Recovery


-


-


-


-


-


-


Technical Revisions


(6,833)


(32)


(6,865)


910


543


(5,864)


Discoveries


68


-


68


51


1,258


329


Acquisitions


594


-


594


6,743


156,277


33,383


Dispositions


(241)


-


(241)


(976)


(21,968)


(4,879)


Economic Factors


(281)


(1)


(282)


(2,760)


(17,044)


(5,882)


Production


(1,694)


(26)


(1,720)


(2,832)


(56,053)


(13,894)

Closing Balance


24,802


424


25,226


55,162


1,018,267


250,098

(1)

"Company Interest" means Bellatrix working interest (operated or non-operated) share before deduction of royalties but
including 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 and shale gas
reserves represent an immaterial portion of the Company's natural gas reserves.

(3)

Opening Balance is as at December 31, 2013 and Closing Balance is as at December 31, 2014.

 


WORKING INTEREST (1) (Gross) RESERVES RECONCILIATION
















Light and
Medium
Crude Oil
(mbbl)


Heavy
Crude Oil
(mbbl)


Total Crude
Oil (mbbl)


NGLs
(mbbl)


Conventional
Natural Gas
(mmcf) (2)


Oil
Equivalent
(mboe)

PROVED PRODUCING













Opening Balance (3)


9,396


104


9,500


11,924


195,675


54,037


Extensions


90


-


90


609


13,405


2,933


Infill Drilling


235


-


235


1,739


40,166


8,669


Improved Recovery


-


-


-


-


-


-


Technical Revisions


1,058


(54)


1,004


4,242


81,692


18,862


Discoveries


57


-


57


43


1,042


273


Acquisitions


58


-


58


1,512


35,036


7,409


Dispositions


(203)


-


(203)


(794)


(17,844)


(3,970)


Economic Factors


11


(1)


10


(90)


(1,435)


(319)


Production


(1,693)


(26)


(1,719)


(2,829)


(55,972)


(13,877)

Closing Balance (3)


9,009


24


9,033


16,356


291,765


74,016

TOTAL PROVED













Opening Balance


18,993


217


19,210


25,842


474,353


124,111


Extensions


483


-


483


1,295


28,324


6,498


Infill Drilling


750


-


750


2,678


60,793


13,560


Improved Recovery


-


-


-


-


-


-


Technical Revisions


(1,716)


20


(1,696)


4,545


67,307


14,067


Discoveries


57


-


57


43


1,042


273


Acquisitions


421


-


421


4,732


109,660


23,429


Dispositions


(203)


-


(203)


(794)


(17,844)


(3,971)


Economic Factors


(12)


(1)


(13)


(1,343)


(12,876)


(3,502)


Production


(1,693)


(26)


(1,719)


(2,829)


(55,972)


(13,877)

Closing Balance


17,079


210


17,289


34,168


654,787


160,589

PROBABLE













Opening Balance


11,568


265


11,833


21,195


326,065


87,372


Extensions


602


-


602


1,139


24,394


5,806


Infill Drilling


794


-


794


1,826


40,173


9,316


Improved Recovery


-


-


-


-


-


-


Technical Revisions


(5,121)


(51)


(5,172)


(3,633)


(66,715)


(19,924)


Discoveries


11


-


11


9


216


55


Acquisitions


173


-


173


1,803


41,797


8,943


Dispositions


(38)


-


(38)


(183)


(4,125)


(908)


Economic Factors


(269)


-


(269)


(1,418)


(4,180)


(2,383)


Production


-


-


-


-


-


-

Closing Balance


7,721


214


7,934


20,738


357,626


88,277

PROVED PLUS PROBABLE













Opening Balance


30,561


482


31,043


47,037


800,418


211,483


Extensions


1,085


-


1,085


2,433


52,718


12,304


Infill Drilling


1,544


-


1,544


4,504


100,966


22,876


Improved Recovery


-


-


-


-


-


-


Technical Revisions


(6,836)


(32)


(6,868)


912


592


(5,857)


Discoveries


68


-


68


51


1,258


329


Acquisitions


594


-


594


6,535


151,457


32,372


Dispositions


(241)


-


(241)


(976)


(21,968)


(4,879)


Economic Factors


(281)


(1)


(282)


(2,760)


(17,055)


(5,884)


Production


(1,693)


(26)


(1,719)


(2,829)


(55,972)


(13,877)

Closing Balance


24,800


424


25,224


54,907


1,012,413


248,866

(1)

"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 and shale gas reserves represent an immaterial portion of the Company's natural gas reserves.

(3)

Opening Balance is at December 31, 2013 and Closing Balance is as at December 31, 2014.

 

TAX POOLS

At December 31, 2014, the Company had approximately $1.64 billion in tax pools available for deduction against future income as follows:











($000s)



Rate %



2014

(unaudited)



2013

Intangible resource pools:











Canadian exploration expenses



100



116,700



99,000


Canadian development expenses



30



758,700



691,500


Canadian oil and gas property expenses



10



207,900



80,200


Foreign resource expenses



10



800



900

Alberta Non Capital losses greater than Federal non-capital losses



(Alberta) 100



16,100



16,100

Undepreciated capital cost (1)



6 – 55



367,600



224,900

Non capital losses (expire through 2030)



100



162,300



94,500

Financing  costs



20 S.L



14,100



15,600

Total Tax Pools






1,644,200



1,222,700

(1)

Approximately $355 million of undepreciated capital cost pools are class 41, which is claimed at a 25% rate.

 

FUTURE DEVELOPMENT COSTS USING FORECAST PRICES AND COSTS

At year-end, 2014, Sproule had evaluated certain future development opportunities on Company lands including 281 gross (207 net) future undrilled Cardium horizontal locations and 185 gross (95 net) evaluated future undrilled Mannville horizontal locations.  Of the 281 Cardium locations, 208 were assigned proved and probable reserves, with 73 assigned probable reserves only.  Of the 185 Mannville locations, 130 were assigned proved and probable reserves, with the remaining 55 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.










($000's)




Proved Future
Development Costs




Proved plus Probable
Future Development
Costs

2015




234,209




369,262

2016




339,453




532,991

2017




203,473




309,953

2018 and subsequent




86,114




123,784

Undiscounted total




863,249




1,335,990

Discounted @ 10%/yr.




742,206




1,151,804

 

RESERVE REPORT COMMODITY PRICING

The following is a summary of the Consultants' Average Forecast Prices as at January 1, 2015:




OIL









Year

Forecast


WTI

Cushing
Oklahoma

($US/bbl)


Edmonton
Par Price

40° API
($Cdn/bbl)


Hardisty
Heavy 12°
API API
($Cdn/bbl)


NATURAL
GAS AECO
($Cdn/

MMBtu)


NATURAL
GAS LIQUIDS
at Edmonton (3)
($Cdn/bbl)


INFLATION
RATES (1)
%/Year


EXCHANGE
RATE (2)
($US/$Cdn)
















2015


64.17


67.89


51.86


3.38


73.48


1.833


0.853

2016


76.67


83.52


63.90


3.83


90.17


1.833


0.868

2017


83.33


90.96


69.64


4.06


98.20


1.833


0.868

2018


87.08


95.26


72.93


4.41


102.69


1.833


0.868

2019


90.67


99.33


76.03


4.76


106.99


1.833


0.868

2020


94.30


103.80


79.45


4.97


111.73


1.833


0.868

2021


96.59


106.16


81.25


5.18


114.26


1.833


0.868

2022


98.36


108.10


82.74


5.36


116.34


1.833


0.868

2023


100.18


110.09


84.25


5.54


118.47


1.833


0.868

2024


102.02


112.13


85.85


5.70


120.67


1.833


0.868

2025


103.88


114.17


87.39


5.80


122.85


1.833


0.868

2026


105.80


116.26


88.98


5.90


125.10


1.833


0.868

2027


107.74


118.41


90.63


6.02


127.40


1.833


0.868

2028


109.74


120.58


92.29


6.12


129.73


1.833


0.868

2029


111.75


122.81


93.97


6.24


132.12


1.833


0.868

Thereafter


+1.83%/yr.


+1.83%/yr.


+1.83%/yr.


+1.83%/yr.


+1.83%/yr.





(1)

Inflation rates for forecasting prices and costs

(2)

Exchange rates used to generate the benchmark reference prices in this table

(3)

Natural Gas Liquids is represented by the pentanes plus price

 

Weighted average historical prices realized by Bellatrix (before commodity price risk management contracts) for the year ended December 31, 2014, were $4.77/mcf for natural gas, $91.41/bbl for crude oil and condensate, and $42.74/bbl for natural gas liquids (excluding condensate).

RESERVES COMMITTEE

Bellatrix 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 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, 2014, Bellatrix had over 385,685 net undeveloped acres in Alberta, British Columbia and Saskatchewan.


Land Statistics



















2014






2013

Average working interest














Developed






61%






62%


Undeveloped






74%






75%

Total






68%






69%

Land Holdings (1)
















2014



2013




Gross



Net



Gross



Net

Developed














British Columbia



9,285



2,765



9,752



2,692


Alberta



462,741



282,478



443,780



272,114


Saskatchewan



13,327



12,720



13,327



12,720


Total



485,353



297,962



466,859



287,526

Undeveloped














British Columbia



106,180



47,208



107,700



47,521


Alberta



405,991



330,835



436,436



360,821


Saskatchewan



7,641



7,641



8,289



8,289


Total



519,812



385,685



552,425



416,631

Developed and Undeveloped














British Columbia



115,465



49,973



117,452



50,213


Alberta



868,732



613,313



880,216



632,935


Saskatchewan



20,968



20,361



21,616



21,009

Total



1,005,165



683,647



1,019,284



704,157

(1) 

May not add due to rounding

 

OPERATIONS OUTLOOK

2015 represents a transformational year for the Company given the strategic infrastructure investment made over the past several years.  The decision to build, maintain, and control operatorship of key strategic infrastructure remains critical to our long term sustainability and growth objectives.  Bellatrix anticipates significant benefits from our infrastructure investment including an improvement in operational reliability, increased revenue from enhanced liquids extraction, and reduced operating costs.  Highlights of Bellatrix's 2015 expected operations include:

  • Construction continues on the Bellatrix O'Chiese Nees-Ohpawganu'ck deep-cut gas plant; all major components included shop welded pipe is on-site with 55% of on-site welding complete.  Critical path items remain on schedule including the express pipeline crossing the North Saskatchewan River, the gas plant condensate line, and finalized integration of mechanical and electrical schedules.  The project remains on budget and on schedule for a start-up by July 1, 2015.
  • Bellatrix's differentiated joint venture strategy provides access to additional third party capital on terms that enhance economic returns, allowing the Company to continue profiting from the further development of its properties even during the current commodity price weakness. Bellatrix expects to access up to $85 million of joint venture capital in 2015, resulting in gross capital spending for the year of up to $285 million. Pursuant to its existing joint venture arrangements, Bellatrix may access up to $250 million of additional joint venture capital in 2016 and beyond. 
  • The 2015 net capital budget of $200 million is comprised of approximately $120 million drilling and completion costs, $70 million facility and infrastructure costs and $10 million land, geological and other related costs.  Bellatrix will revisit its capital budget on a continuous basis, will pursue accretive monetization opportunities, and will further curtail capital spending, if necessary, in order to preserve its balance sheet until commodity prices firmly recover.
  • Despite commodity price headwinds in 2015, the Company remains acutely focused on profitability for our shareholders. Bellatrix maintains a deep inventory of highly profitable drilling opportunities at today's commodity prices, and has an active risk management program to support 2015 objectives. 

 

COMMODITY RISK MANAGEMENT CONTRACTS

Bellatrix has the following crude oil and natural gas commodity price risk management contracts in place for 2015. 





Q1 2015



Q2 2015



Q3 2015



Q4 2015

Natural gas volumes (mmcf/d)



47.2



156.7



156.7



85.9

Average price ($/mcf) (1)



$3.13



$2.93



$2.93



$2.94














Oil volumes (bbl/d)



1,967



3,000



3,000



3,000

Average fixed price ($/bbl) (2)



$70.34



$70.34



$70.34



$70.34

(1)

The conversion of $/GJ to $/mcf is based on an average corporate heat content rate of 40.8Mj/m3.

(2)

Oil hedges are Canadian dollar WTI equivalent.

 

Bellatrix recently added to its 2015 risk management program with the addition of 87 mmcf/d of natural gas fixed price swaps for March 1 through March 31, 2015 at C$3.24/mcf.  Including our previously announced hedging contracts, the Company has protected approximately 90% of forecast natural gas volumes through the spring and summer season (March through October) compared with the mid-point of our current annual average production guidance range.

Bellatrix Exploration Ltd. is a Western Canadian based growth oriented oil and gas company engaged in the exploration for, and the acquisition, development and production of oil and natural gas reserves in the provinces of Alberta, British Columbia and Saskatchewan.  Common shares of Bellatrix trade on the Toronto Stock Exchange and on the New York Stock Exchange under the symbol BXE. 

All amounts in this press release are in Canadian dollars unless otherwise identified.

READER ADVISORIES:

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 press release 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 2014 FINANCIAL INFORMATION: As Bellatrix plans to announce its audited 2014 financial results on or about March 12, 2015, certain financial information for the year ended December 31, 2014 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: This press release 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 GAAP as an indicator of the Company's performance. Therefore reference to 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 this press release. Funds flow from operations per share is calculated using the weighted average number of shares for the period. This press release also contains the term of operating netbacks, which is not a recognized measure under GAAP. Operating netbacks are calculated by subtracting royalties, transportation, and operating expenses from revenues before other income. Management believes this measure is a useful supplemental measure of the amount of revenues received after transportation, royalties and operating expenses. Readers are cautioned, however, that this measure should not be construed as an alternative to net profit or loss determined in accordance with GAAP as a measure of performance. Bellatrix's method of calculating this measure may differ from other entities, and accordingly, may not be comparable to measures used by other companies.

ADDITIONAL GAAP MEASURES:  This press release also contains the term net debt. The reference to the additional GAAP measure of net debt may not be comparable with the calculation of similar measures for other entities. The Company's calculation of net debt includes long-term debt and the net working capital deficiency (excess). The net working capital deficiency (excess) excludes short-term commodity contract assets and liabilities, current finance lease obligation, and current deferred lease inducements.

FORWARD LOOKING STATEMENTS:  Statements in this document may contain forward-looking information including management's assessment of future plans and operations, production forecasts used to calculate reserve life, reserve life calculations, reserves estimates, anticipated additional drilling locations, the total future capital associated with development of drilling locations and reserves, 2015 capital expenditures and expected amount of total program including capital to be invested by various joint venture partners, method of funding thereof and nature of expenditures, infrastructure and facilities plans and timing and status thereof, anticipated benefits from our infrastructure investment including an expected improvement in operational reliability, expected increased revenue from enhanced liquids extraction, and expected reduced operating costs, the expectation that Bellatrix's joint venture strategy will provide access to additional third party capital on terms that enhance economic returns that is expected to allow the Company to continue profiting from the further development of its properties even during the current commodity price weakness, the intention of Bellatrix to revisit its capital budget on a continuous basis, to pursue accretive monetization opportunities, and to further curtail capital spending, if necessary, in order to preserve its balance sheet until commodity prices firmly recover, the expectations that Bellatrix has a deep inventory of highly profitable drilling opportunities at today's commodity prices, the expectation that Bellatrix's risk management program will support 2015 objectives, the expectation of the percentage of 2015 production guidance that is protected by natural gas commodity risk management contracts, Bellatrix's strategy and future objectives, and timing of release of 2014 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; 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; field production rates and decline rates; the ability to replace and expand oil and natural gas reserves through acquisition, development and exploration; the timing and costs of pipeline, storage and facility construction and expansion and the ability of the Company to secure adequate product transportation and processing; 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.


Source: PR Newswire (March 9, 2015 - 7:30 AM EDT)

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