CALGARY, Alberta, Nov. 13, 2019 (GLOBE NEWSWIRE) — Prairie Provident Resources Inc. (“Prairie Provident”, “PPR” or the “Company”) is pleased to announce its operating and financial results for the three and nine months ended September 30, 2019. PPR’s consolidated financial statements (“Financial Statements”) and related Management’s Discussion and Analysis (“MD&A”) for the three and nine months ended September 30, 2019 are available on our website at www.ppr.ca and filed on SEDAR.
Prairie Provident continued to successfully execute its strategic plan during the third quarter of 2019, delivering strong operational performance and responsibly maintaining stable production volumes while generating positive adjusted funds flow1 and solid operating netbacks1 despite continued uncertain market conditions. Subsequent to quarter end, the Company’s lenders confirmed continuation of the borrowing base under PPR’s senior secured revolving note facility (the “Revolving Facility”) at US$60 million and extended the maturity date to April 30, 2021, which preserve the Company’s financial flexibility. Financial covenants are unchanged.
HIGHLIGHTS
- Production averaged 6,214 boe/d (68% liquids) in the third quarter and 6,188 boe/d (68% liquids) for the first nine months of 2019, an increase of 8% and 19%, respectively, compared to the corresponding periods in 2018 and in line with guidance. The production increase was driven by a successful development program which contributed 593 boe/d and 400 boe/d of production in the third quarter and the first nine months of 2019, respectively, and incremental production volumes from the Marquee Energy Ltd. acquisition completed in Q4 2018.
- PPR generated $11.0 million ($19.24/boe) of operating netback1 before the impact of derivatives in the third quarter of 2019. After the realized loss on derivatives, PPR generated $10.8 million ($18.95/boe) of operating netback, representing a 15% total increase (7% on a per unit basis) from the third quarter of 2018, as higher production, lower royalties and lower realized derivative losses outweighed the impact from lower realized oil prices.
- Operating expense was $18.92/boe for the third quarter, at the low end of our guidance. Compared to the first and second quarters of 2019, operating expense improved by $4.55/boe and $1.44/boe, respectively. While the first quarter 2019 operating expense was negatively impacted by extreme weather, the third quarter operating expense level was more reflective of PPR’s expected run-rate.
- Positive adjusted funds flow1, excluding $0.4 million of decommissioning settlements, totaled $6.6 million ($0.04 per basic share and diluted share) in the third quarter, an increase of 7% from the same period last year due to higher production and an improved operating netback. Strong adjusted funds flow realized during the third quarter contributed to a strengthened balance sheet, positioning PPR to internally fund our planned 2019 capital program.
- Net loss totaled $2.3 million in the third quarter of 2019 compared to a net loss of $2.6 million in the same period last year, primarily driven by non-cash items.
1 Non-IFRS measure – see below under “Non-IFRS Measures”
- Overall net debt1 was reduced during the third quarter primarily due to adjusted funds flow1 exceeding net capital expenditures1, partially offset by weakening of the Canadian dollar against the US dollar. As at September 30, 2019, net debt totaled $112.1 million, a decrease of $1.3 million and $5.2 million from June 30, 2019 and December 31, 2018, respectively, as PRR continues to prioritize debt reduction and strengthening its balance sheet. PPR’s 2019 budget forecast for capital expenditures is expected to under-spend projected adjusted funds flow at current strip pricing, preserving the Company’s financial flexibility to pursue future growth opportunities organically or through acquisition.
- Net capital expenditures1 during the third quarter and first nine months of 2019 were in line with guidance and totaled $1.9 and $8.8 million, respectively. Third quarter 2019 expenditures were primarily directed to recompleting one well in the Provost area, facility work at Evi and a 3D seismic program in the Princess area. With the volatility in both West Texas Intermediate and Canadian oil price differentials late in 2018, PPR elected to take a conservative approach in the first nine months of 2019 by reducing capital spending relative to the prior year with a focus on strengthening the balance sheet.
- At Evi, an independent reserves evaluation as of May 31, 2019 assigned an incremental 2.1 MMboe of proved plus probable (“P+P”) undeveloped reserves (97% oil and liquids) to future waterflood expansions, comprised of approximately 1.6 MMboe of proved undeveloped reserves and approximately 0.5 MMboe of probable undeveloped reserves, with a total estimated net present value of future net revenue (before tax and discounted at 10%) on a P+P basis of $30 million. 2 The incremental reserves assignments increased PPR’s total estimated corporate reserves volumes by 7.1% on a proved basis and by 6.1% on a P+P basis, relative to year-end estimates.
- Subsequent to September 30, 2019, PPR’s lenders confirmed continuation of the borrowing base under the Revolving Facility at US$60 million, extended the maturity date of the Company’s senior secured revolving note facility (“Revolving Facility”) from October 31, 2020 to April 30, 2021, and removed the “term-out” feature so as to keep the facility as a revolving facility for the remainder of the term. Financial covenants are unchanged. The next borrowing base re-determination for the Revolving Facility will be on or about March 31, 2020.
- As of September 30, 2019, PPR had US$58.0 million of borrowings drawn against the US$60.0 million Revolving Facility, comprised of US$30.0 (CAD$40.5 million equivalent using exchange rate at the time of borrowing) of CAD-denominated borrowing and US$28.0 million of USD-denominated borrowing (CAD$37.1 million equivalent using the September 30, 2019 exchange rate of $1.00 USD to $1.32 CAD). There were also US$30.6 million (CAD$40.6 million equivalent using the September 30, 2019 exchange rate) of senior subordinated notes due October 31, 2021 outstanding at the quarter-end, for total borrowings of US$88.6 million or CAD$117.4 million at September 30, 2019 exchange rate.
- PPR satisfied its remaining $1.8 million of Canadian Exploration Expense expenditure commitment related to its October 2018 flow-through share financing.
1 Non-IFRS measure – see below under “Non-IFRS Measures”
2 The incremental reserves assignments are based on an independent reserves evaluation of the Company’s interests in respect of specific reserve entities within three future undeveloped waterflood expansion areas in Evi. The evaluation was conducted by Sproule Associates Limited (“Sproule”), independent qualified reserves evaluators, with an effective date of May 31, 2019, and supplements Sproule’s year-end evaluation of the Company’s total corporate reserves as at December 31, 2018. For additional details, please refer to the Company’s news release dated September 18, 2019 (available at www.ppr.ca) and related material change report dated September 18, 2019 (filed on SEDAR and available under PPR’s issuer profile at www.sedar.com).
FINANCIAL AND OPERATING SUMMARY
Three Months Ended September 30, | Nine Months Ended September 30, | |||||||
($000s except per unit amounts) | 2019 | 2018 | 2019 | 2018 | ||||
Production Volumes | ||||||||
Crude oil (bbls/d) | 4,029 | 4,044 | 4,051 | 3,552 | ||||
Natural gas (Mcf/d) | 12,092 | 9,607 | 11,792 | 9,056 | ||||
Natural gas liquids (bbls/d) | 169 | 131 | 172 | 120 | ||||
Total (boe/d) | 6,214 | 5,776 | 6,188 | 5,181 | ||||
% Liquids | 68 | % | 72 | % | 68 | % | 71 | % |
Average Realized Prices | ||||||||
Crude oil ($/bbl) | 61.83 | 69.83 | 61.81 | 67.84 | ||||
Natural gas ($/Mcf) | 1.14 | 1.35 | 1.57 | 1.53 | ||||
Natural gas liquids ($/bbl) | 25.53 | 52.61 | 30.26 | 52.66 | ||||
Total ($/boe) | 43.01 | 52.33 | 44.29 | 50.40 | ||||
Operating Netback ($/boe)1 | ||||||||
Realized price | 43.01 | 52.33 | 44.29 | 50.40 | ||||
Royalties | (4.85 | ) | (9.04 | ) | (4.57 | ) | (7.89 | ) |
Operating costs | (18.92 | ) | (18.81 | ) | (20.86 | ) | (19.47 | ) |
Operating netback | 19.24 | 24.48 | 18.86 | 23.04 | ||||
Realized losses on derivative instruments | (0.29 | ) | (6.77 | ) | (1.02 | ) | (5.48 | ) |
Operating netback, after realized losses on derivative instruments | 18.95 | 17.71 | 17.84 | 17.56 | ||||
Notes:
1 Operating netback is a Non-IFRS measure (see “Non-IFRS Measures” below).
Capital Structure ($000s) |
As at September 30, 2019 |
As at December 31, 2018 |
||
Working capital (deficit)1 | 2.7 | (16.1 | ) | |
Long-term debt | (114.8 | ) | (101.1 | ) |
Total net debt2 | (112.1 | ) | (117.3 | ) |
Debt capacity3 | 2.7 | 21.8 | ||
Common shares outstanding (in millions) | 171.3 | 171.9 | ||
Notes:
1 Working capital (deficit) is a non-IFRS measure (see “Non-IFRS Measures” below) calculated as current assets less current portion of derivative instruments, minus accounts payable and accrued liabilities.
2 Net debt is a non-IFRS measure (see “Non-IFRS Measures” below), calculated by adding working capital (deficit) and long-term debt.
3 Debt capacity reflects the undrawn capacity of the Company’s revolving facility of USD$60 million at September 30, 2019 and USD$65 million at December 31, 2018, converted at an exchange rate of $1.0000 USD to $1.3243 CAD on September 30, 2019 and $1.0000 USD to $1.3642 CAD on December 31, 2018.
Three Months Ended September 30, | Nine Months Ended September 30, | |||||
Drilling Activity | 2019 | 2018 | 2019 | 2018 | ||
Gross wells | — | — | 1.0 | 8.0 | ||
Net (working interest) wells | — | — | 1.0 | 8.0 | ||
Success rate, net wells (%) | N/A | N/A | 100 | % | 100 | % |
OPERATIONS REVIEW
Princess, AB
PPR’s most recent well in the southern portion of our high-value, low decline light oil play in the Princess area was completed and brought on production in June 2019, averaging production of 386 boe/d (37% liquids) in the third quarter of 2019. With a total capital cost of approximately $1.6 million to drill, complete, equip and tie-in, the well is expected to pay out after ten months under current commodity price assumptions. PPR is currently drilling one development well and one stratigraphic well. Current production from the Princess area is approximately 1,300 boe/d (70% liquids).
Michichi, AB
During the first half of 2019, PPR acquired leases on 4.25 sections of undeveloped lands in the Michichi/Wayne area as part of the elimination of PPR’s capital commitment and purchased natural gas rights in areas where PPR currently holds petroleum leases. The Michichi area continues to contribute approximately 2,450 boe/d (45% liquids) to overall production with a significant inventory of high-quality future drilling locations to support longer-term growth.
Evi, AB
Total current production from the Evi area is approximately 1,850 boe/d (97% liquids) and includes incremental production from the two gross (2.0 net) light oil Slave Point wells completed and brought on production in February 2019.
2019 OUTLOOK AND GUIDANCE
With a continued focus on its balance sheet and enhancing per share metrics, PPR’s capital allocation decisions will be regularly assessed as the Company continues to responsibly manage its inventory of high-quality future drilling locations. Supported by a successful 2019 development program and strong adjusted funds flow generated year-to-date, Prairie Provident’s disciplined 2019 capital budget of $14.2 million is expected to be funded with internally-generated adjusted funds flow. Due to recent widening of WCS differentials, the Company has decided to defer the drilling of one well to the first quarter of 2020 to preserve liquidity and development economics. As such, the Company expects its average full-year production to be at the low end of its 2019 guidance.
ABOUT PRAIRIE PROVIDENT
Prairie Provident is a Calgary-based company engaged in the exploration and development of oil and natural gas properties in Alberta. The Company’s strategy is to grow organically in combination with accretive acquisitions of conventional oil prospects, which can be efficiently developed. Prairie Provident’s operations are primarily focused at the Michichi and Princess areas in Southern Alberta targeting the Banff, the Ellerslie and the Lithic Glauconite formations, along with an established and proven waterflood project at our Evi area in the Peace River Arch. Prairie Provident protects its balance sheet through an active hedging program and manages risk by allocating capital to opportunities offering maximum shareholder returns.
For further information, please contact:
Prairie Provident Resources Inc.
Tim Granger President and Chief Executive Officer
Tel: (403) 292-8110
Email: tgranger@ppr.ca