Obsidian Energy Ltd. Announces New Chairman of the Board of Directors, 126 Percent Reserve Replaceme

CALGARY, Feb. 22, 2018 /PRNewswire/ - OBSIDIAN ENERGY LTD. (TSX/NYSE – OBE) ("Obsidian Energy", the "Company", "we", "us" or "our") is pleased to announce that Jay W. Thornton has been appointed as Chairman of the Obsidian Energy Board of Directors (the "Board"), effectively immediately. Mr. George Brookman, who has been the Acting Chair since August 8, 2017, will remain as a director on the Board.

"On behalf of the Board, I would like to thank Mr. George Brookman for his leadership as Acting Chair over the last several months," commented Mr. Thornton. "George stepped in after the tragic passing of our previous Chairman, Rick George, and guided the Company with energy and thoughtful diligence. I look forward to continuing to steward our base strategy while exploring all opportunities to unlock shareholder value from our significant asset base."

Mr. Thornton has served on the Board since June 26, 2013 and has over 27 years of oil and gas experience, holding various operating and corporate executive positions with Shell Canada and Suncor Energy Inc. He is currently a director of North American Energy Partners Inc. and Tervita Corporation, and was previously a director with the Canadian Association of Petroleum Producers (CAPP). He is a graduate of McMaster University with an Honours degree in Economics. He also completed the Institute of Corporate Directors (ICD) Education Program.

2017 Year-End Reserves Summary

The Company is pleased to present the results of its year-end 2017 independent reserves evaluation, prepared by Sproule Associates Limited ("Sproule").

"Our year-end 2017 reserves highlight the revitalized operational delivery of the business," commented David French, President & CEO. "2017 was the first time in five years we replaced produced reserves, and grew both our proved ("1P") and proved plus probable ("2P") volumes. It is gratifying to see the recognition of our field results by our reserve evaluator.

Our updated book reflects the low decline nature of our Cardium waterflood business, and a conservative future development profile with plenty of upside. Continued recognition of the waterflood potential in our portfolio grew our 2P liquids weighting by six percent, and we hold a robust 2P reserve life index of 12 years. Adding reserves at just over $13 per boe through 2017 demonstrates a powerful engine to reward investors. We look forward to putting our capital to work."

The financial and operating information in this press release is based on estimates and is unaudited. Some of the terms below do not have standardized meanings. Further detail can be found in the "Oil and Gas Advisory" section contained in this release. This evaluation was prepared in accordance with definitions, standards, and procedures set out in the Canadian Oil and Gas Evaluation Handbook ("COGEH") 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 our Annual Information Form which will be filed on SEDAR, EDGAR, and posted to our website, on or about March 7, 2018. All numbers are shown prior to the impact of 2018 disposition activity unless otherwise noted.

Replaced Over 100 Percent of Produced Reserves for the First Time in Five Years

Increased conviction in inventory quality, high confidence in undeveloped book additions and efficient development activity drove strong reserve replacement across the business. We replaced 126 percent of 2017 production on a 2P reserves basis, 131 percent on a 1P reserves basis and 121 percent on a proved developed producing ("PDP") reserves basis.

Integrated Waterflood is Paying Dividends by Lowering Cardium Operated Development Costs

Cardium operated development costs were $14.12 per boe, down 24 percent from year-end 2016 and 47 percent from year-end 2015. Reserve volumes associated with waterflood recovery, over and above primary development, now sit at 8.4 mmboe. The amount of future development capital ("FDC") associated with this waterflood specific volume is approximately $94 million. As we continue to demonstrate decline performance in our base wells, we expect waterflood reserve volumes to increase without the need for additional future development capital.

Total Corporate operated development costs for 2017 were $13.27 per boe. 2P finding and development ("F&D") costs, including changes in future development capital, were $1.72 per boe. These costs reflect updates to our undeveloped book to account for low cost integrated waterflood development.

Commercial Trades Increased Liquids Weighting by Six Percent

Through the disposition of natural gas weighted production in the first quarter of 2017 and gas oil ratio suppression across our waterflood acreage, our 2P liquids weighting increased by six percent, to 67 percent total liquids. Including our 2018 legacy asset disposition, our 2P liquids weighting increased to 69 percent.

The liquids weighting in our reserve book exceeds our 2018 forecasted weighting, representing the light oil growth potential of the business through increased focus on integrated waterflood development in the Cardium.

Low Decline Rate Supports Seven Year PDP Reserve Life

Our reserve book assumes an average decline rate of 16 percent in the next three years, demonstrating the sustainable production and cash flow inherent in our Cardium waterflood business. Based on Q4 2017 production and year-end 2017 reserves adjusted for disposition activity, PDP, 1P and 2P reserve life index ("RLI") is 7 years, 8 years and 12 years, respectively.

Formal Recognition of Deep Basin Potential and Upside to Undeveloped Book

Sproule has formally recognized the potential of our Deep Basin position, with five undeveloped locations across the Mannville and Rock Creek formations. Our total undeveloped reserve book remains conservative and highly achievable, with approximately 200 total locations booked, including approximately 130 in the Cardium.

Net Asset Value ("NAV") Demonstrates Highly Confident and Fundable Upside in the Business

Despite $55 million of negative pricing impacts, 2P net present value ("NPV") 10 percent grew to $1.71 billion, relative to year-end 2016 A&D adjusted NPV10 of $1.67 billion. Our 2P NPV per share, adjusted for debt, equates to approximately $2.60 per share. Our PDP NPV per share, adjusted for debt, equates to approximately $1.50 per share.

2017 Year-End Reserves Tables

In 2017, we engaged Sproule, an independent, qualified engineering firm, to evaluate one hundred percent of our 1P and 2P reserves. Sproule conducted an independent reserves evaluation of Obsidian Energy's reserves effective December 31, 2017. This evaluation was prepared in accordance with definitions, standards, and procedures set out in COGEH and NI 51-101. The Sproule reserves evaluation was based on Sproule's December 31, 2017 forecast prices and costs. Reserves included below are Company gross reserves which are the Company's total working interest reserves before the deduction of any royalties and excluding any royalty interests payable to the Company. The numbers in the tables below may not add due to rounding.

Summary of Reserves

 

Reserves Reconciliation – Proved

 

Reserves Reconciliation – Proved Plus Probable

 

Summary of Before Tax Net Present Values

 

Future Development Capital ("FDC")

 

Summary of Pricing and Inflation Rate Assumptions

 

Year-End 2017 Financial Results Conference Call Details

Obsidian Energy plans to release its financial results for the year ended December 31, 2017 before markets open on Wednesday, March 7, 2018. A conference call will be held to discuss the results at 6:30 a.m. MST (8:30 a.m. EST) that morning.

To listen to the conference call, please call 647-427-7450 or 1-888-231-8191 (toll-free). This call will be broadcast live on the Internet and may be accessed directly at the following URL:

http://event.on24.com/wcc/r/1602755-1/F3B454234B7BA6D9E327EEC65E28F03E

A digital recording will be available for replay two hours after the call's completion, and will remain available until March 21, 2018, 21:59 Mountain Time (23:59 Eastern Time). To listen to the replay, please dial 416-849-0833 or 1-855-859-2056 (toll-free) and enter Conference ID 1898936, followed by the pound (#) key.

Oil and Gas Advisory

This press release contains a number of oil and gas metrics, including "FDC", "F&D costs", "Operated Development Costs", "NAV", and "RLI" which do not have standardized meanings or standard methods of calculation and therefore such measures may not be comparable to similar measures used by other companies. Such metrics have been included herein to provide readers with additional measures to evaluate the Company's performance; however, such measures are not reliable indicators of the future performance of the Company and future performance may not compare to the performance in previous periods. FDC is the sum of all booked capital. F&D costs are the sum of exploration and development costs incurred in the period, plus the change in estimated FDC for the reserves category, all divided by the change in reserves during the period. F&D costs exclude the impact of acquisitions and divestitures. Operated Development Costs are the sum of drill, complete, equip, and tie-in costs to bring operated wells spud in the period on production, divided by the reserves added from these wells.  NPV per share, adjusted for debt, is synonymous for NAV, and is based on the present value of future net revenues discounted at 10% before tax, adjusted for unaudited net debt as at December 31, 2017. The NPV per share is divided by the number of Obsidian Energy shares outstanding as at December 31, 2017. Reserves life index is calculated as total Company gross reserves divided by unaudited fourth quarter 2017 production.

Under NI 51-101, proved reserves estimates are defined as having a high degree of certainty to be recoverable with a targeted 90 percent probability in aggregate that actual reserves recovered over time will equal or exceed proved reserve estimates. For proved plus probable reserves under NI 51-101, the targeted probability is an equal (50 percent) likelihood that the actual reserves to be recovered will be greater or less than the proved plus probable reserve estimate. The reserve estimates set forth below are estimates only and there is no guarantee that the estimated reserves will be recovered. Actual reserves may be greater than or less than the estimates provided herein.

Abbreviations Contained in the Press Release