CALGARY, ALBERTA–(Marketwired – Feb. 7, 2017) – Bonterra Energy Corp. (www.bonterraenergy.com) (TSX:BNE) (“Bonterra” or “the Company”) is pleased to provide the summary results of its independent reserve report (the “Sproule Report”) prepared by Sproule Associates Limited (“Sproule”) with an effective date of December 31, 2016.
Corporate Reserves Information
The following summarizes certain information contained in the Sproule Report. The Sproule Report was prepared in accordance with the definitions, standards and procedures contained in the Canadian Oil and Gas Evaluation Handbook (“COGE Handbook”) and National Instrument 51-101 – Standards of Disclosure for Oil and Gas Activities (“NI 51-101”). Additional reserve information as required under NI 51-101 will be included in the Company’s Annual Information Form which will be filed on SEDAR on or by March 14, 2017.
Reserve Report Highlights
- Increased proved plus probable (P+P) reserves by five percent to 94.9 million BOE (71 percent oil and liquids) and total proved reserves by five percent to 74.3 million BOE (71 percent oil and liquids).
- Increased proved reserves by 3.6 million BOE which replaced production by 177 percent.
- Total proved reserves represent 78 percent of total P+P reserves.
- Reserves per fully diluted share (P+P) increased to 2.85 BOE per share compared to 2.78 BOE per share from the prior year, an increase of 3 percent.
- Finding Development and Acquisition (FD&A) costs including the change in future development capital (FDC) are $9.93 per BOE on a P+P basis which results in a recycle ratio of 2.3 times.
- FD&A costs including the change in FDC are $10.87 per BOE on a total proved basis which results in a recycle ratio of 2.1 times.
- Reserve life index of approximately 20 years on a P+P basis, 16 years on a total proved basis, and 9 years on a proved developed producing (PDP) basis (based on 2016 average production rate of 12,650 BOE per day).
Summary of Gross Oil and Gas Reserves as of December 31, 2016
|Light and Medium Oil||Solution Gas||Natural Gas||Natural Gas Liquids||Oil equivalent(4)||Future Development Capital|
|Total P+P(1) (2) (3)||60,320||141,840||25,429||6,707||94,905||566,241|
|(1) Reserves have been presented on gross basis which are the Company’s total working interest share before the deduction of any royalties and without including any royalty interests of the Company.|
|(2) Totals may not add due to rounding.|
|(3) Based on Sproule’s December 31, 2016 escalated price deck.|
|(4) Oil equivalent amounts have been calculated using a conversion rate of six thousand cubic feet of natural gas to one barrel of oil.|
Reconciliation of Company Gross Reserves by Principal Product Type as of December 31, 2016 (1)(2)
|Conventional Natural Gas||Natural Gas
|Proved||Proved + Probable||Proved||Proved + Probable||Proved||Proved + Probable||Proved||Proved + Probable|
|Opening Balance, December 31, 2015||47,036||59,558||111,172||146,128||5,118||6,708||70,684||90,621|
|Extensions & Improved Recovery(2)||3,363||4,233||8,447||10,454||366||460||5,138||6,437|
|Closing Balance, December 31, 2016(4)||47,581||60,320||129,108||167,269||5,157||6,707||74,257||94,905|
|(1) Gross Reserves means the Company’s working interest reserves before calculation of royalties, and before consideration of the Company’s royalty interests.|
|(2) Increases to Extensions & Improved Recovery include infill drilling and are the result of step-out locations drilled by Bonterra and other operators on and near Company-owned lands.|
|(3) Includes volumes associated with Farm outs.|
|(4) Totals may not add due to rounding.|
Summary of Net Present Values of Future Net Revenue as of December 31, 2016
|($M)||Net Present Value Before Income Taxes Discounted at (% per Year)|
|Total proved plus probable(1)(2)(3)||3,284,941||1,973,222||1,364,823||1,026,716|
|(1) Evaluated by Sproule as at December 31, 2016. Net present value of future net revenue does not represent fair value of the reserves.|
|(2) Net present values equals net present value before income taxes based on Sproule’s forecast prices and costs as of December 31, 2016. There is no assurance that the forecast prices and costs assumptions will be attained and variances could be material.|
|(3) Includes abandonment and reclamation costs as defined in NI 51-101.|
Finding, Development & Acquisition (FD&A) and Finding & Development (F&D) Costs
The Company has historically been active in its capital development program and through 2016 successfully reduced capital costs per well through a combination of efficiencies and benefitting from reductions to the overall industry cost structure. Over the past three years, Bonterra has incurred the following FD&A(3) and F&D(3) costs both excluding and including Future Development Capital:
|Proved Reserve Net Additions||P+P Reserve Net Additions|
|2016||2015||2014||3 Yr Avg(4)||2016||2015||2014||3 Yr Avg(4)|
|FD&A Costs per BOE (1)(2)(3)|
|F&D Costs per BOE (1)(2)(3)|
|(1) Barrels of Oil Equivalent may be misleading, particularly if used in isolation. A BOE conversion ratio of 6 MCF: 1 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.|
|(2) 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.|
|(3) FD&A and F&D costs are net of proceeds of disposal and the FD&A costs per BOE are based on reserves acquired net of reserves disposed of.|
|(4) Three year average is calculated using three year total capital costs and reserve additions on both a Proved and P+P reserves on a weighted average basis.|
Certain financial and operating information, such as production information, and finding and development costs included in this press release for the quarter and year ended December 31, 2016 are based on estimated unaudited financial results for the year and are subject to the same limitations as discussed under Forward Looking Statements set out below. These estimated amounts may change upon the completion of audited financial statements for the year ended December 31, 2016 and changes could be material.
Bonterra continued to realize operational success through 2016 as it focused on projects offering the highest economics while preserving value in a persistently low commodity price environment. The Company realized ongoing success in its core Pembina Cardium area through 2016 and maintained stable production volumes as a result of its very low corporate decline rate of approximately 18 – 20 percent, successful drilling program and the implementation of innovative completions techniques across its asset base.
During the fourth quarter of 2016, the Company experienced production curtailments primarily related to pipeline restrictions which resulted in 360 BOE per day being off-line for the fourth quarter. The Company also experienced freeze-off conditions in November and December and has not yet been able to quantify the reduced volumes. All restricted volumes were produced and stored in inventory and will be included in Q1 2017 production.
Bonterra’s 2016 full year and fourth quarter production summary follows:
- Average daily production for the full year of 12,650 BOE per day (70 percent oil and liquids), in line with 2016 guidance, and unchanged relative to the 12,656 BOE per day average in 2015;
- Average daily production of 12,134 BOE per day in the fourth quarter, a decrease of three percent compared to the fourth quarter of 2015, primarily related to pipeline restrictions and freeze-offs, reducing Q4 production by approximately 360 BOE per day; and,
- Production per fully diluted share was 0.14 BOE per share in 2016, which was the same as the prior year, reflecting constant production volumes and shares outstanding year over year.
- Bonterra drilled and uncompleted three gross (1.5 net) wells in Q4 2016 which were completed, tied-in and brought on production early in 2017.
The Company has not released its audited 2016 financial results, and therefore the financial figures provided herein are estimates and are unaudited.