Bonterra Energy Corp. announces its operating and financial results for the three month period ended March 31, 2021.
Q1 2021 FINANCIAL & OPERATING SNAPSHOT
Production averaged 11,909 BOE per day in Q1 2021, 18 percent higher than the preceding quarter, reflecting a successful drilling program that re-commenced in the fourth quarter of 2020, along with the reactivation of wells that had been voluntarily shut-in due to low commodity prices.
Realized oil and gas sales totaled $48.8 million in Q1 2021, a 54 percent increase over Q4 2020 and 27 percent higher than Q1 2020, due primarily to significantly improved realized commodity pricing and increased production volumes compared to Q4 2020.
Generated funds flow1 of $16.6 million in the quarter ($0.50 per share), a 522 percent increase over the preceding quarter, and 13 percent higher than Q1 2020.
Capital expenditures totaled $23.5 million in Q1 2021, with $19.3 million directed to the drilling of 13 gross (12.9 net) wells and the completion, equip and tie-in of 14 gross (13.8 net) wells, four of which were drilled in 2020. Three of the 13 wells drilled in Q1 were placed on production in early Q2 2021. The balance of the capital was allocated primarily to related infrastructure and recompletions.
Drilling, completion and equipping costs in the first quarter averaged $1.4 million per well, representing a 32 percent decrease from Q1 2020.
Continued to focus on incremental operating cost savings across the organization, with Q1 2021 per unit production costs declining to $15.60 per BOE, representing a ten percent decrease from Q4 2020 and a two percent decrease from Q1 2020.
Field netbacks1 averaged $24.56 per BOE in Q1 2021, a 73 percent and 34 percent increase over Q4 2020 and Q1 2020, respectively, reflecting significantly higher revenue and lower per unit production costs, offset by a realized loss on risk management contracts and increased per unit royalty expenses in the period.
Net debt1 totaled $328.5 million as at March 31, 2021, a $12.9 million increase from year-end, reflecting the impact of a more active capital program that is designed to return production to pre-COVID-19 levels.
In keeping with good governance practices, Bonterra recently made changes to its Board of Directors (the "Board"), appointing Mr. D. Michael G. Stewart to the Board and then to Board Chair, assuming the role from Mr. George Fink. The Company also confirmed that Mr. Randy Jarock will not stand for re-election at Bonterra's upcoming annual and special meeting of shareholders to be held on May 20, 2021.
QUARTER IN REVIEW
Bonterra benefitted from strengthening commodity prices in Q1 2021 as stability returned to markets following extreme volatility throughout 2020. With a successful drilling and completions program for Q1 2021, the Company has started 2021 positioned for success. During the first three months of 2021, Bonterra strategically grew production volumes into a higher commodity price environment, resulting in higher sales revenue and funds flow and reduced per unit costs.
Production averaged 11,909 BOE per day1 for the first three months of 2021, an increase of 18 percent over Q4 2020 and in-line with Q1 2020, as execution of the Company's 2021 capital program continued, which is designed to enable Bonterra to meet or exceed pre-COVID-19 production volumes. Higher average production was paired with reduced operating costs of $15.60 per BOE, driving cost decreases of 10 percent relative to Q4 2020 and two percent from Q1 2020. As the majority of the production from new wells drilled and completed during Q1 2021 averaged only 35 days on production, Bonterra anticipates greater benefit from these wells will be realized in its second quarter results.
The Company invested $23.5 million in capital expenditures during Q1 2021, representing approximately 36 percent of the lower end of its annual capital budget, with $19.3 million directed to the drilling of 13 gross (12.9 net) wells and the completion, equip and tie-in of 14 gross (13.8 net) wells, of which four of the completed and equipped wells were drilled in 2020. Three of the 13 wells drilled in Q1 2021 were placed on production in early Q2 2021. Relative to Q1 2020, Bonterra reduced drilling, completion and equipping costs in Q1 2021 by approximately 32 percent, supporting robust capital efficiencies. The balance of the capital in the quarter was spent primarily on related infrastructure and recompletions.
In addition to undertaking new drilling activity in the quarter, Bonterra also remained committed to efficiently manage decommissioning liabilities and has entered into the province of Alberta's Area-Based Closure ("ABC") program to reduce abandonment and reclamation costs and liabilities. During the first three months of 2021, the Company successfully abandoned 84.0 net wells supported by the Alberta Site Rehabilitation Program ("SRP"), and anticipates abandoning a further 223.8 net wells through the balance of 2021 and 2022, representing approximately 60 percent of Bonterra's total inactive wells.
Shortly before the end of the quarter, Obsidian Energy Ltd. ("Obsidian") confirmed that they would not proceed with their hostile bid, and allowed the extended expiry date to lapse. As the hostile bid was unsuccessful, any Bonterra shares that had been tendered will be promptly returned to the respective Bonterra shareholders. The Company appreciates the ongoing support and feedback received from shareholders through the process.
OUTLOOK
Bonterra is pleased to reiterate its previously issued guidance, including plans to maintain a fully-funded capital program between $65 and $75 million targeting high rate-of-return, low-risk light oil opportunities. Based on this capital program, the Company expects 2021 annual production to average between 12,800 to 13,200 BOE per day2, an increase of approximately 30 percent over Q4 2020. Exit production for Q1 2021 was approximately 12,800 BOE per day3, signaling the accomplishment of Bonterra's goal to restore production to pre-COVID-19 levels, and positioning the Company to benefit from rising commodity prices and a lean cost structure, both of which are contributing factors to higher funds flow.
Building on its existing risk management program, and as part of Bonterra's ongoing efforts to diversify commodity pricing and to protect future cash flows, the Company has put in place physical delivery sales and risk management contracts, details of which are included in Note 12 to the financial statements. For the remainder of 2021, Bonterra has secured a WTI price between $36.00 USD to $50.50 USD per bbl on 2,500 bbls per day, with a WTI to Edmonton par differential average of $7.18 on 2,250 bbls per day. For the first quarter of 2022, Bonterra has secured a WTI price between $48.00 and $68.50 USD per bbl on 2,250 bbls per day, with a WTI to Edmonton par differential average of $5.00 on 250 bbls per day. In addition, the Company has secured an average natural gas price of $2.55 on 7,638 GJ per day through the end of Q1 2022. Overall, risk management contracts are in place for approximately 30 percent of Bonterra's anticipated crude oil and natural gas production until the end of Q1 2022.
Bonterra believes the Company is well positioned to continue pursuing profitable development of its high-quality, light oil weighted asset base. The Company plans to drive strong and sustainable free cash flow, supported by its 2021 capital expenditure program and growing production into a higher commodity price environment, and is proud of its established track record of thriving regardless of market conditions. Bonterra will continue to prioritize good environmental, social and governance ("ESG") initiatives, including being a positive and meaningful contributor to the economic success of the communities where it operates in central Alberta, employing local services and upholding stringent safety measures to ensure the health and well-being of its employees, contractors and partners.
