Bellatrix Announces 2018 Year End Reserves Highlighted by 13% Reserve Growth and Low Cost Reserve Additions

TSX: BXE

CALGARY, March 14, 2019 /CNW/ – Bellatrix Exploration Ltd. (“Bellatrix” or the “Company”) (TSX: BXE) announces 2018 year end reserves, highlighted by 13% reserve growth and low cost reserve additions.

Reserves at December 31, 2018 were independently evaluated by InSite Petroleum Consultants Ltd. (“InSite”).  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”) and the Canadian Oil and Gas Evaluation Handbook (“COGE Handbook”).

2018 YEAR END RESERVE HIGHLIGHTS

Bellatrix delivered low cost reserve additions in 2018 with 13% growth in each of Proved Developed Producing (“PDP”), Proved (“1P”), and Proved plus Probable (“2P”) reserve categories.  The Company achieved a 100% success rate through the drill bit, focused on the low cost Spirit River liquids rich natural gas play.

In 2018, Bellatrix drilled and/or participated in 14 gross (9.2 net) total wells including 10 gross (7.7 net) operated Spirit River liquids rich natural gas wells, 1 gross (1.0 net) operated Cardium well and 3 gross (0.5 net) non-operated wells (two Spirit River and one Cardium). Bellatrix’s operated drilling activity in 2018 included, a total of 49,027 meters drilled, 18,026 meters of which was horizontal length.

Bellatrix demonstrated strong results within its core area in 2018 highlighted by the following achievements:

Total 1P and 2P reserves at year end 2018 increased to 193 mmboe and 265 mmboe, respectively, representing 13% growth within each category, driven by strong positive technical reserve revisions and infill drilling additions which more than offset the impact of reserves produced during the year.

Achieved reserves replacement of 330% in 2018 including the effect of total net acquisitions, and 166% reserve replacement excluding the effect of total net acquisitions in 2018.

Bellatrix established a December 31, 2018 2P net asset value (2P net present value discounted at 10% (“NPV10”) before tax) of $1.12 billion ($13.84/share) which incorporates future net revenue adjusted for year end total net debt, seismic, and land value.

The 2018 year end PDP NPV10 before tax value of $472.5 million remained relatively unchanged from the 2017 year end PDP NPV10 value of $475.3 million as the 13% growth in reserve volumes mitigated the impact of lower forecast natural gas and natural gas liquids prices year over year.

Bellatrix maintained a focused capital program in 2018 adding PDP reserves at a finding, development and acquisition (“FD&A”) cost of $3.12/boe excluding capital invested in the Bellatrix O’Chiese Nees-Ohpawganu’ck deep-cut gas plant at Alder Flats (the “Alder Flats Plant”), and $3.22/boe including the Alder Flats Plant. The PDP recycle ratio excluding Alder Flats Plant capital was 2.7 times.

Bellatrix’s 2P and 1P FD&A costs including changes in future development capital (“FDC”) in 2018 averaged $1.99/boe and $2.28/boe, respectively. On a three year average basis (2016 to 2018), Bellatrix delivered strong 2P and 1P FD&A costs of $3.22/boe and $3.76/boe, respectively.

The Company’s calculated 1P and 2P reserve life indices improved year over year to 14.7 years and 19.2 years (compared with 13.5 and 17.4 years in 2017), respectively.

Bellatrix’s corporate decline rate forecast by InSite for PDP reserves in 2019 is 26% (relatively unchanged compared with an estimated first year PDP decline rate at December 31, 2017 of 25%).

2018 HIGHLIGHTS

Twelve months ended December,

2018

2017

Reserves (Working Interest (1), mboe)

Proved Developed Producing

77,327

65,305

Total Proved

192,979

171,198

  Proved Undrilled/Total Proved

59%

61%

Total Proved and Probable

265,222

235,330

Probable/Total Proved and Probable

27%

27%

Net Present Value of Reserves (Before Tax, 10% Discount Rate) (2)

Total Proved ($MM)

$1,049

$1,016

Proved and Probable ($MM) (3)

$1,500

$1,501

Net Asset Value

Proved and Probable ($MM) (4)

$1,120

$1,161

Proved and Probable Net Asset Value, per basic share (5)

$13.84

$23.52

FD&A Costs (Including Changes in FDC)

PDP, excluding Alder Flats Plant capital ($/boe)

$3.12

$4.81

1P, excluding Alder Flats Plant capital ($/boe)

$2.28

$4.12

2P, excluding Alder Flats Plant capital ($/boe)

$1.99

$3.15

3 year average 1P ($/boe)

$3.76

$4.05

3 year average 2P ($/boe)

$3.22

$2.39

Selected Key Operating Statistics

Annual average sales volumes (boe/d)

35,635

36,872

Q4 average sales volumes (boe/d)

35,001

37,077

Annual operating netback ($/boe) (6)

$8.51

$9.02

Total net debt ($MM) (6)

$443.3

$420.8

Reserve Life Index (Years)

Proved

14.7

13.5

Proved and Probable

19.2

17.4

Recycle Ratio

PDP, excluding change in FDC and Alder Flats Plant capital

2.7 x

1.9 x

1P, excluding change in FDC and Alder Flats Plant capital

3.8 x

3.8 x

2P, excluding change in FDC and Alder Flats Plant capital

4.7 x

4.1 x

Evaluated Future Horizontal Drilling Locations (7)

Gross Spirit River

174

177

Net Spirit River

132

129

Gross Cardium

150

147

Net Cardium

127

117

  (1) “Working Interest” means Bellatrix’s working interest (operated or non-operated) share excluding any royalty interest and before deduction of royalties and is also referred to as “Gross” reserves under NI 51-101. May not add due to rounding.

(2) It should not be assumed that the present worth of estimated future net revenue presented in the tables above or elsewhere in this press release represents the fair market value of the reserves. There is no assurance that the forecast prices and costs assumptions will be attained and variances could be material. The recovery and reserves estimates of Bellatrix’s crude oil and natural gas reserves provided herein are estimates only and there is no guarantee that the estimated reserves will be recovered. Actual crude oil, natural gas and natural gas liquids reserves may be greater than or less than the estimates provided herein.

(3) Bellatrix reserves information includes the impact of IFRS 16, which changes the accounting treatment of certain operating leases so that the future lease payments associated with such leases are recognized as a financial liability on the Company’s balance sheet. As a result, for the purposes of preparing the reserves data presented herein, the lease payments associated with such leases are recognized as financing costs rather than as operating costs and have not been deducted in calculating the value of the Company’s reserves. If such lease payments were recognized as operating costs in calculating the value of the Company’s reserves, it would result in a reduction to the Company’s 2P NPV10 future net revenue by $88 million from approximately $1.5 billion to $1.412 billion.

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

(5) Based on 80.9 million common shares outstanding as at December 31, 2018 (excluding common shares issuable pursuant to securities that are convertible, exercisable or exchangeable into common shares).

(6) The terms “operating netback” and “total net debt” do not have standard meanings under Canadian generally accepted accounting principles (“GAAP”).   Operating netback is calculated by deducting transportation, royalties and operating costs from revenue. Operating netback includes the impact of commodity price risk management contracts.  The Company’s calculation of total net debt excludes other deferred liabilities, deferred capital obligations, long-term risk management contract liabilities, decommissioning liabilities, and deferred tax liabilities. Total net debt includes the adjusted working capital deficiency, long term loans receivable, 8.5% senior unsecured notes due 2020 (the “Senior Notes”), 8.5% second lien notes due 2023 (the “Second Lien Notes”), 6.75% convertible unsecured subordinated debentures due 2021 (the “Convertible Debentures”) (liability component), and current and long term amounts outstanding under our syndicated revolving credit facilities (the “Credit Facilities”). The adjusted working capital deficiency is calculated as net working capital deficiency excluding current risk management contract assets and liabilities, current portion of other deferred liabilities, current portion of deferred capital obligation and the current Credit Facilities. See “Non-GAAP measures” in the Reader Advisories at the end of this Press Release. 

 (7) Represents proved plus probable undeveloped locations included in the InSite Report as defined below.

2018 RESERVES

Bellatrix engaged InSite to complete a reserve report in accordance with NI 51-101, on 100% of Bellatrix’s oil and gas properties effective December 31, 2018 (the “InSite Report”).  Highlights include:

265.2 million boe total working interest 2P reserves and 193.0 million boe 1P reserves.

$1.5 billion net present value of future net revenue of 2P reserves before tax at a 10% discount rate.

A net asset value of $13.84 per basic share outstanding based on the InSite evaluation of 2P reserves at a 10% discount rate.

Bellatrix’s corporate decline rate forecast by InSite for PDP reserves in 2019 is 26% (relatively unchanged compared with an estimated first year PDP decline rate at December 31, 2017 of 25%).

Working interest

2018 Reserves

2017 Reserves

Oil & Liquids

Natural Gas

Total

Total

Variance

(mbbl)

(mmcf)

(mboe)

(mboe)

%

Proved

62,308

784,024

192,979

171,198

13%

Probable

23,421

292,934

72,243

64,132

13%

Proved Plus Probable (1)  

85,729

1,076,957

265,222

235,330

13%

(1) Totals may not add due to rounding.

NET ASSET VALUE – PROVED PLUS PROBABLE

The following table of net asset value, as at December 31, 2018, is based on the InSite evaluation of future net revenue of the Company’s 2P reserves before tax, which does not represent fair market value.

($000s except acre, unit and per unit amounts)

PV 0%

PV 5%

PV 8%

PV 10%

PV 15%

Proved plus Probable Reserves (1)

3,793,797

2,246,652

1,743,453

1,500,254

1,083,970

Undeveloped Lands (2)

35,952

35,952

35,952

35,952

35,952

Value of Seismic (3)

26,872

26,872

26,872

26,872

26,872

Total Net Debt (4)

(443,332)

(443,332)

(443,332)

(443,332)

(443,332)

Net Asset Value

3,413,289

1,866,144

1,362,945

1,119,746

703,462

Per Basic Common Share (5)

$42.19

$23.06

$16.85

$13.84

$8.69

 (1) As evaluated by InSite as at December 31, 2018 based on forecast prices and costs before income tax.

(2) As estimated by Bellatrix as at December 31, 2018 based on 133,815 net acres of undeveloped land at an average price of $268.67

per acre.

(3)Based on 25% of $105.7 million replacement value based on seismic costs to buy data at an average of approximately $1,600/km for 2D and $16,000/km2 for 3D.

(4) The Company’s calculation of total net debt excludes other deferred liabilities, deferred capital obligations, long-term risk management contract liabilities, decommissioning liabilities, and deferred tax liabilities. Total net debt includes the adjusted working capital deficiency, long term loans receivable, Second Lien Notes, Senior Notes, Convertible Debentures (liability component), current Credit Facilities and long term Credit Facilities. The adjusted working capital deficiency is calculated as net working capital deficiency excluding current risk management contract assets and liabilities, current portion of other deferred liabilities, current portion of deferred capital obligation and the current Credit Facilities.

(5) Based on 80.9 million common shares outstanding as at December 31, 2018 (excluding common shares issuable pursuant to securities that are convertible, exercisable or exchangeable into common shares).

NET PRESENT VALUE (“NPV”) OF FUTURE NET REVENUE

The forecast prices used in the InSite Report incorporate InSite’s commodity price forecasts as at December 31, 2018 (“InSite Forecast Prices”) which are noted below under the heading “Reserve Report Commodity Pricing”.  It should not be assumed that the NPV estimated by InSite represents the fair market value of Bellatrix’s reserves.  Estimated future net revenues are reduced for estimated future abandonment and reclamation costs (for wells (both current and future wells) that have been attributed reserves), estimated royalties payable, estimated operating costs, and estimated capital for future development associated with the reserves.

In the InSite Report, the net total future capital over the life of the reserves associated with 1P reserves is $679 million ($512 million discounted at 10%) and $863 million ($639 million discounted at 10%) for 2P reserves. The change in 2018 net total FDC over the life of the reserves associated with 1P reserves is $15 million ($1 million discounted at 10%) and $31 million ($7 million discounted at 10%) for 2P reserves.  Calculated changes in net FDC exclude future capital from acquired properties.

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

As at December 31, 2018

0%

5%

8%

10%

15%

Proved

Developed producing

887,468

619,667

522,192

472,545

382,630

Developed non-producing

18,791

13,685

11,690

10,637

8,654

Undeveloped

1,506,640

885,604

671,650

566,101

382,763

Total proved

2,412,899

1,518,956

1,205,532

1,049,283

774,047

Probable

1,380,898

727,696

537,921

450,971

309,923

Total proved plus probable

3,793,797

2,246,652

1,743,453

1,500,254

1,083,970

(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, 2018

0%

5%

8%

10%

15%

Proved

Developed producing

887,468

619,667

522,192

472,545

382,630

Developed non-producing

18,791

13,685

11,690

10,637

8,654

Undeveloped

1,245,226

763,538

590,955

503,942

348,934

Total proved

2,151,485

1,396,890

1,124,837

987,124

740,218

Probable

1,022,509

545,391

407,431

344,313

241,878

Total proved plus probable

3,173,994

1,942,281

1,532,268

1,331,437

982,096

 (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)

The Company achieved another strong year of capital investment in 2018 with average drill, complete, equip and tie-in costs for its Spirit River program in 2018 averaging approximately $3.4 million per well (down from $3.8 million in 2017).

Total exploration and development capital expenditures in 2018 (before acquisition and divestiture activities) were $50.3 million.  Total net capital expenditures after acquisition and divestiture activities were $75.6 million in 2018.

2018

2017

2016

2016 –

2018 Avg.

PROVED PLUS PROBABLE FD&A COSTS

Excluding changes in FDC

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

Exploration and development (2)

2.32

3.39

1.77

2.46

Acquisitions (excluding dispositions) (3)

1.43

0.04

3.26

1.35

Total (including acquisitions)

1.88

2.43

2.02

2.12

Total excluding Alder Flats Plant capital (4)

1.82

2.22

1.82

1.96

Including changes in FDC (2)

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

Exploration and development

1.44

3.58

3.68

3.16

Acquisitions (excluding dispositions) (3)

2.66

2.83

5.80

3.35

Total (including acquisitions)

2.05

3.36

4.03

3.22

Total excluding Alder Flats Plant capital (4)

1.99

3.15

3.83

3.05

PROVED FD&A COSTS

Excluding changes in FDC

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

Exploration and development (2)

2.62

3.42

1.88

2.59

Acquisitions (excluding dispositions) (3)

1.94

0.05

4.34

1.79

Total (including acquisitions)

2.31

2.61

2.22

2.38

Total excluding Alder Flats Plant capital (4)

2.24

2.38

1.99

2.20

Including changes in FDC (2)

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

Exploration and development

1.41

4.67

3.75

3.62

Acquisitions (excluding dispositions) (3)

3.51

3.33

6.99

4.14

Total (including acquisitions)

2.36

4.34

4.20

3.76

Total excluding Alder Flats Plant capital (4)

2.28

4.12

3.98

3.57

PROVED DEVELOPED PRODUCING FD&A COSTS

FD&A Costs, PDP ($/boe)

Exploration and development (2)

3.51

5.56

5.02

4.83

Acquisitions (excluding dispositions) (3)

2.84

0.47

11.14

4.11

Total (including acquisitions)

3.22

5.27

5.90

4.67

Total excluding Alder Flats Plant capital (4)

3.12

4.81

5.30

4.31

(1) FD&A costs are used as a measure of capital efficiency. FD&A presented above has been calculated based on exploration and development capital and/or acquisition capital spent in the applicable period (both including and excluding changes in future development capital for that period) divided by the change in reserves for that period including revisions for that same period. Bellatrix provides FD&A costs that incorporate all acquisitions and exclude the reserve, capital, and FDC impact of dispositions during the year.  The foregoing calculation is based on working interest reserves.

(2) 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. 

(3) 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.

(4) In 2018, the Company completed facilities and equipment investments totalling $50.3 million including approximately $2.6 million directly on the Alder Flats Plantas such capital is non-recurring and no further development capital will be required to be spent on the Alder Flats Plant in future years, total FD&A costs are shown excluding capital spent directly on the Alder Flats Plant.

RESERVE LIFE INDEX

Bellatrix’s reserve life index has been determined for 1P and 2P working interest reserves using forecast prices and costs.  The reserve life index for 2018 is calculated by dividing reserves as at December 31, 2018 by 2019 forecasted average production of 37,853 boe/d for 2P reserves and 35,824 boe/d for 1P reserves, as set forth in the InSite 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.

2018

2017

2016

2015

2014

Proved

14.7

13.5

14.1

10.1

10.6

Proved and Probable

19.2

17.4

18.8

14.3

13.3

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

Recycle ratio is a measure for evaluating the effectiveness of a company’s reinvestment program and 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 2018, the Company completed facilities and equipment investments totalling $50.3 million including approximately $2.6 million directly on the Alder Flats Plant.  Capital spent directly on the Alder Flats Plant has been excluded from the calculation of recycle ratio as such capital is non-recurring and no further development capital will be required to be spent on the Alder Flats Plant in future years.

As at December 31, 2018

Proved

Developed

Producing

Proved

Proved

and

Probable

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

$8.51

$8.51

$8.51

Recycle ratio (excluding change in FDC)

2.64

3.68

4.53

Recycle ratio (excluding change in FDC and Alder Flats Plant capital)

2.73

3.80

4.68

(1) Operating netback is calculated by deducting transportation, royalties and operating costs from revenue and includes the impact of commodity price risk management contracts. (See Non-GAAP Measures)

FUTURE DEVELOPMENT COSTS USING FORECAST PRICES AND COSTS

At year end, 2018, InSite had evaluated certain future development opportunities on Company lands including 174 gross (132 net) future undrilled Spirit River horizontal locations and 150 gross (127 net) future undrilled Cardium horizontal locations representing proved plus probable undeveloped locations.

For purposes of assigning net present value of future revenue, future development costs were committed as detailed in the following table.

($000s)

Proved Future Development

Costs

Proved plus Probable Future

Development Costs

2019

54,270

57,720

2020

116,465

121,269

2021

135,577

160,503

2022 and subsequent

372,284

523,511

Undiscounted total

678,596

863,002

Discounted @ 10%/yr.

511,629

639,408

RESERVES SUMMARY

The InSite Report is based on forecast prices and costs, and applies InSite’s forecast escalated commodity price deck, foreign exchange rate, and inflation rate assumptions as at December 31, 2018 as outlined in the table below entitled “Reserve Report Commodity Pricing”. At December 31, 2018 the Company’s 2P gross reserves as evaluated by InSite, using forecast prices and costs, were 265,222 mboe, an increase of 13% compared to 235,330 mboe at December 31, 2017; total 1P gross reserves were 192,979 mboe, an increase of 13% compared to 171,198 mboe at December 31, 2017.  By commodity type, natural gas made up 68% and crude oil and natural gas liquids 32% of total 2P 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 which management anticipates will be filed on or about March 21, 2019.

Reserves, at December 31, 2018, as evaluated by InSite, are summarized below and in the following tables.

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

Forecast Prices and Costs

As at Dec. 31, 2018

As at Dec. 31, 2017

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

319,094

6

953

23,186

77,327

65,305

Developed non-producing

5,919

0

46

337

1,369

837

Undeveloped

459,011

114

1,925

35,742

114,283

105,057

Total proved

784,024

120

2,924

59,264

192,979

171,198

Probable

292,934

198

1,367

21,856

72,243

64,132

Total proved plus probable

1,076,957

318

4,291

81,120

265,222

235,330

(1) “Working Interest” means Bellatrix’s working interest (operated or non-operated) share excluding any royalty interest and 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, 2018

As at Dec. 31, 2017

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

288,710

6

866

18,626

67,617

56,640

Developed non-producing

4,961

0

42

236

1,104

688

Undeveloped

412,635

99

1,579

30,447

100,897

92,277

Total proved

706,306

105

2,487

49,309

169,618

149,604

Probable

262,378

166

1,095

17,829

62,819

55,090

Total proved plus probable

968,684

271

3,581

67,138

232,438

204,694

 (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.  

RESERVE REPORT COMMODITY PRICING

The following is a summary of InSite’s forecast commodity prices as at December 31, 2018:

Year

Forecast

WTI Oil

Cushing

Oklahoma

($US/bbl)

Edmonton

Crude Oil

Ref Price

 ($/bbl)

AECO

Natural Gas

($/MMBtu)

Butane

($/bbl)

Propane

($/bbl)

Condensate

($/bbl)

Exchange

Rate (1)

($US/$Cdn)

2019

57.00

63.50

1.90

20.96

28.58

67.95

0.76

2020

64.00

75.55

2.29

37.02

33.24

78.95

0.78

2021

68.00

80.50

2.71

45.89

37.03

83.72

0.80

2022

71.00

83.25

3.03

54.95

38.30

86.58

0.80

2023

72.80

85.60

3.21

58.21

41.52

88.60

0.80

2024

74.50

87.62

3.33

61.33

42.93

90.68

0.80

2025

76.50

90.01

3.44

62.10

44.10

93.16

0.80

2026

77.50

92.68

3.50

63.95

45.41

95.92

0.80

2027

79.05

94.53

3.57

65.22

46.32

97.84

0.80

2028

80.63

96.42

3.65

66.53

47.25

99.79

0.80

Thereafter

+2.0%/yr.

+2.0%/yr.

+2.0%/yr.

+2.0%/yr.

+2.0%/yr.

+2.0%/yr.

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

Weighted average historical prices realized by Bellatrix (before commodity price risk management contracts) for the year ended December 31, 2018, were $1.78/mcf for natural gas, $73.63/bbl for crude oil and condensate, and $24.46/bbl for natural gas liquids (excluding condensate).

LAND

As at December 31, 2018, Bellatrix had approximately 133,815 net undeveloped acres in Alberta, British Columbia, and Saskatchewan.

Land Holdings (1)

2018

2017

Gross

Net

Gross

Net

Developed

British Columbia

7,602

1,910

8,132

2,108

Alberta

366,664

230,940

371,715

227,180

Saskatchewan

13,327

12,720

13,327

12,720

Total

387,593

245,570

393,174

242,008

Undeveloped

British Columbia

62,637

20,318

79,987

28,859

Alberta

142,313

105,764

153,035

112,213

Saskatchewan

8,005

7,732

8,005

7,732

Total

212,956

133,815

241,028

148,804

Developed and Undeveloped

British Columbia

70,240

22,228

88,120

30,967

Alberta

508,977

336,705

524,751

339,393

Saskatchewan

21,332

20,452

21,332

20,452

Total

600,549

379,385

634,202

390,812

(1) May not add due to rounding

Bellatrix Exploration Ltd. is a publicly traded 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, with highly concentrated operations in west central Alberta, principally focused on profitable development of the Spirit River liquids rich natural gas play.

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