CALGARY, Alberta, Feb. 22, 2022 (GLOBE NEWSWIRE) -- (PIPE – TSX) Pipestone Energy Corp. (“Pipestone” or the “Company”) is pleased to provide an update on its operations with record quarterly production achieved; and to report its year-end 2021 independent reserves evaluation prepared by McDaniel & Associates Consultants Ltd. (“McDaniel”) with an effective date of December 31, 2021 (the “McDaniel Report”).

Recent Operations Highlights:

  • Record Production Volumes: Q4 2021 production averaged 28,623 boe/d (30% condensate, 44% total liquids), the highest quarterly production since inception. Production during Q4 2021 was impacted by several cold weather-related outages at 3rd party midstream facilities;
  • 2021 Production Guidance Achieved: 2021 production averaged 24,584 boe/d(1) (31% condensate, 45% total liquids) within previously announced guidance of 24,000 – 26,000 boe/d; and
  • Record Quarterly Operating Netback: The Company realized continued improvement in operating netback in Q4 2021 to a corporate record of $25.06/boe (inclusive of $8.45/boe in realized hedging losses), an increase of 14% over Q3 2021, and a 148% increase over Q4 2020.

2021 Reserve Highlights(1):

  • Pipestone delivered 28% growth in Proved Developed Producing (“PDP”) reserves from 31.7 MMboe in 2020 to 40.5 MMboe and achieved a Finding & Development (“F&D”) cost of $10.37/boe, coupled with a full year 2021 operating netback of $27.72/boe (exclusive of hedging losses) drives a 2021 PDP F&D recycle ratio(2) of 2.7x;
  • Total Proved (“1P”) reserve volumes increased year-over-year by 20% from 134 MMboe to 160 MMboe with an F&D recycle ratio(2) of 3.9x;
  • Total Proved plus Probable (“2P”) reserve volumes increased year-over-year by 21% from 228 MMboe to 275 MMboe with an F&D recycle ratio(2) of 6.6x;
  • Increase in 1P Future Development Capital (“FDC”) of 11% from $640 million to $708 million, and a 6% increase in 2P FDC from $935 million to $989 million, which is equivalent to approximately 5 years at our 2022 capital spending budget;
  • Go-forward estimated undeveloped 1P F&D cost (FDC / Undeveloped Reserves) of $6.15/boe ($6.33/boe at YE 2020) and Undeveloped 2P F&D cost of $4.62/boe ($5.03/boe at YE 2020) reflect the continued efficiencies achieved in the business during 2021; and
  • Updated 1P and 2P Net Asset Value per Share (“NAVPS”) of $6.03 and $9.43 per fully diluted share, respectively, utilizing a 10% discount rate at a flat price deck (US$80/bbl WTI, C$3.50/GJ AECO, $0.80 CADUSD, no inflation). These NAVPS values reflect a premium of 36% and 113%, for 1P and 2P respectively, over the current share price of $4.42.
  (1) 2021 annual production volumes, capital expenditures and operating netbacks referenced throughout this press release are unaudited. All reserve volumes are reported on a net working interest, gross of royalties basis.
  (2) Recycle Ratio is calculated by dividing Operating Netback per boe by F&D costs per boe. 2021 Operating Netback (unaudited) used to calculate Recycle Ratio is exclusive of realized hedging impacts and is calculated as revenue less royalties, operating, and transportation costs. Operating Netback is a non-GAAP measure, see “Advisories” for further details.

Operations Update:

Development Map:

An infographic accompanying this announcement is available at https://www.globenewswire.com/NewsRoom/AttachmentNg/ab1d192e-186d-4203-b449-559feabf88ff

Development Program:

Pipestone successfully executed on all of its planned Q4 2021 development activities. During the quarter, the Company drilled 6 wells on the 2-31 pad, which were subsequently completed in early 2022. These wells are now equipped and will be on production by the end of February. Also, during the fourth quarter, Pipestone drilled 3 wells on the 6-30 pad, which were completed in early January and will also be on production by the end of February. In early January, Pipestone began drilling operations at the 2-25 pad and is currently on the last of four planned wells, with completions currently scheduled for Q1 2022. Approximately $3 million of capital spending originally planned for 2022 was accelerated into Q4 2021 in order to gain operational efficiencies. Total estimated capital expenditures for 2021 are approximately $184 million.

Production & Well Results:

Based on field estimates, Pipestone is pleased to confirm it met its previously announced average corporate production target for November and December 2021 of 30,000 boe/d with average production of 30,809 boe/d. As a result, Pipestone delivered record quarterly production of 28,623 boe/d in Q4 2021, which represents an increase of 16% over Q3 2021 and an increase of 61% over Q4 2020. During Q4 2021, the Company brought 3 new wells at the 6-13 pad on production with a shorter average lateral length of approximately 2,400 metres, which have achieved an average IP90 of 493 bbl/d wellhead condensate and 4.6 MMcf/d raw gas (condensate gas ratio “CGR” of ~107 bbl/MMcf). Based on these results and an actual achieved DCE&T cost of $4.9 million, the company forecasts these wells to payback in approximately 4 months from being brought on production at a flat price deck (US$80/bbl WTI, C$3.50/GJ AECO, $0.80 CADUSD).

On the 14-4 delineation pad, Pipestone drilled two Montney ‘B’ (2,920 metre average lateral length) wells which were brought on production in November 2021. The two Montney ‘B’ wells are in-line with expectations, achieving an IP90 of 330 bbl/d and 3.4 MMcf/d raw gas (CGR of ~97 bbl/MMcf). These wells are forecast to produce ~85 Mbbls of wellhead condensate over the first 12 months on production. Based on these results and an actual achieved DCE&T cost of $5.9 million, the Company forecasts these wells to payback in approximately 7 months from being brought on production at a flat price deck (US$80/bbl WTI, C$3.50/GJ AECO, $0.80 CADUSD). A Lower Montney ‘D’ well on the 14-4 pad tested with significant gas deliverability, averaging 4.4 MMcf/d raw gas and 365 bbl/d condensate, but with an elevated H2S content of 11%, requiring the well to be shut-in while awaiting the installation of blending equipment. Based on a current field average H2S content of 4 – 5%, Pipestone is capable of accommodating higher sulphur content wells through blending.

In H1 2022, the Company expects to bring on stream 13 additional wells, which will underpin its 2022 annual production growth. The Company also continues to evaluate alternatives to contract incremental gas processing capacity, which it expects to contractually secure prior to the end of Q1 2022.
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