FINANCIAL AND OPERATIONAL HIGHLIGHTS
Three months ended | Nine months ended | ||||
As at and for the periods ended |
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FINANCIAL | |||||
Revenue - realized oil and gas sales | 84,909 | 88,827 | 237,778 | 297,043 | |
Funds flow(1) | 42,722 | 35,454 | 106,863 | 144,438 | |
Per share - basic | 1.15 | 0.98 | 2.87 | 4.04 | |
Per share - diluted | 1.14 | 0.95 | 2.86 | 3.87 | |
Cash flow from operations | 37,715 | 48,810 | 95,587 | 148,059 | |
Per share - basic | 1.01 | 1.35 | 2.57 | 4.14 | |
Per share - diluted | 1.01 | 1.30 | 2.56 | 3.96 | |
Net earnings | 13,486 | 17,696 | 29,970 | 61,759 | |
Per share - basic | 0.36 | 0.49 | 0.81 | 1.73 | |
Per share - diluted | 0.36 | 0.47 | 0.80 | 1.65 | |
Capital expenditures | 36,130 | 20,452 | 112,469 | 67,127 | |
Total assets | 955,484 | 948,259 | |||
Net debt(2) | 167,449 | 187,128 | |||
Bank debt | 26,613 | 74,524 | |||
Shareholders' equity | 512,479 | 461,199 | |||
OPERATIONS | |||||
Light oil | -bbl per day | 7,177 | 6,649 | 7,176 | 7,207 |
-average price ($ per bbl) | 104.32 | 111.44 | 97.77 | 116.57 | |
NGLs | -bbl per day | 1,410 | 1,206 | 1,272 | 1,119 |
-average price ($ per bbl) | 49.19 | 64.45 | 49.08 | 68.41 | |
Conventional natural gas | -MCF per day | 34,241 | 31,052 | 32,669 | 31,333 |
-average price ($ per MCF) | 3.06 | 4.73 | 3.27 | 5.47 | |
Total barrels of oil equivalent per day (BOE)(3) | 14,294 | 13,031 | 13,893 | 13,548 |
(1) | Funds flow is not a recognized measure under IFRS. For these purposes, the Company defines funds flow as funds provided by operations including proceeds from sale of investments and investment income received excluding the effects of changes in non-cash working capital items and decommissioning expenditures settled. |
(2) | Net debt is not a recognized measure under IFRS. The Company defines net debt as current liabilities less current assets plus long-term bank debt, subordinated debt, subordinated debentures and subordinated term debt. |
(3) | BOE may be misleading, particularly if used in isolation. A BOE conversion ratio of 6 MCF: 1 bbl is based on an energy conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead. |
FINANCIAL & OPERATING HIGHLIGHTS
- Production in Q3 2023 averaged 14,294 BOE per day, a three percent and ten percent increase over Q2 2023 and Q3 2022, respectively, and averaged 13,893 BOE per day in the first nine months of the year, reflecting Bonterra's continued efficient deployment of capital and the outperformance of new wells brought onstream to date in 2023.
- Funds flow[1] totaled
$42.7 million ($1.14 per fully diluted share) in Q3 2023, increasing 23 percent and 20 percent over Q2 2023 and Q3 2022, respectively. During the first nine months of the year, funds flow totaled$106.9 million ($2.86 per fully diluted share). - Free funds flow1 totaled
$6.6 million in the quarter, directed to reducing net debt, and further advancing the Company's goal of reinstating a sustainable return of capital framework. - Net earnings in the third quarter demonstrated full cycle profitability and totaled
$13.5 million ($0.36 per diluted share), compared to$8.8 million and$17.7 million in Q2 2023 and Q3 2022, respectively; in the first nine months of 2023, net earnings totaled$30.0 million ($0.80 per diluted share). - Field netbacks1 averaged
$40.38 per BOE in Q3 2023, an increase of 10 percent and 12 percent over Q2 2023 and Q3 2022; cash netbacks in the same period averaged$32.48 per BOE, an increase of 17 percent and 10 percent over Q2 2023 and Q3 2022, respectively, supported by higher field netbacks and streamlined general and administrative ("G&A") expenses per BOE. - Production costs of
$16.61 per BOE in Q3 2023 decreased by two percent and 18 percent compared to Q2 2023 and Q3 2022, respectively, due to lower well maintenance costs for well reactivations and the benefit of higher volumes from new wells which drive reduced per unit costs. Production costs for the first nine months of 2023 were$17.00 per BOE, a five percent decrease over the same period in 2022. - Capital expenditures in the quarter totaled
$36.1 million , of which$27.5 million was directed to the drilling of 12 gross (11.8 net) operated wells while 13 gross (13.0 net) operated wells were completed, equipped, and tied-in. Consistent with the end of Q2, Bonterra continued to have three drilled but uncompleted development wells at quarter-end. Two of the three wells were placed on production early in Q4 2023 and the remaining well is expected to be placed on production early in Q1 2024. Within the capital expenditures for the quarter, Bonterra drilled an explorationMontney well which was completed subsequent to quarter-end. The well is in early stages of flow back with an extended flow test planned in 2024. - Net debt1 totaled
$167.4 million atSeptember 30, 2023 , representing a one percent decline from the previous quarter but a nine percent decrease from Q1 2023, a period during which the Company front end weighted its 2023 capital program. Bank debt at quarter-end decreased by 25 percent overJune 30, 2023 , reflecting a streamlined capital program combined with increased production levels and enhanced cash flow.
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1 Non-IFRS measure. See advisories later in this press release. |
QUARTER IN REVIEW
Building on the successful execution of the Company's 2023 drilling and completions program to date, Bonterra's production profile increased to 14,294 BOE per day in Q3 2023 and averaged 13,893 BOE per day for the nine months ended
In addition to generating strong production and robust funds flow during the period, Bonterra executed a disciplined Q3 2023 capital expenditure program which included expanding the Company's operational footprint by drilling and completing its first
Revenue, Netbacks and Funds Flow
The price of crude oil and liquids remained elevated during the third quarter due to the ongoing impact of the
Revenue from oil and gas sales in the third quarter increased 12 percent over the previous quarter due to the combination of higher realized crude oil prices and increased average production, but was four percent lower than the same period in 2022. While Bonterra's third quarter production is weighted approximately 60 percent to crude oil and liquids and 40 percent to natural gas, on a revenue weighting basis, crude oil and liquids represent approximately 89 percent of revenue while natural gas represents 11 percent, providing support for the Company to continue focusing on oil and liquids weighted opportunities.
Field netbacks in the third quarter averaged
Bonterra continued to post positive net earnings in the three and nine month periods ended
Modest Capital Program and Ongoing Reclamation
Through the first nine months of 2023, Bonterra invested
The Company continues to responsibly pursue abandonment and reclamation efforts and in the first nine months of the year, leveraged support from the Alberta Site Rehabilitation Program ("SRP"), which concluded in Q2 2023. To the end of
Drilling and Completion of First Montney Test Well
Bonterra's first
With a significant
OUTLOOK
Bonterra is pleased to reaffirm previously released 2023 guidance as outlined in the Company's
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1 2023 volumes are anticipated to be comprised of 7,000 bbl/d light and medium crude oil, 1,200 bbl/d NGLs and 32,400 mcf/d of conventional natural gas based on a midpoint of 13,600 BOE/d. |
Dividend Triggers
Having a proven history of returning capital to shareholders, Bonterra remains committed to implementing a sustainable return of capital model that is underpinned by forecast free funds flow and a strategic hedging program. Under its return of capital framework, the Company intends to prioritize sustainability and responsible free funds flow1 allocation, with dividend triggers including a targeted net debt range of
Risk Management Drives Sustainability
In order to protect future cash flows, diversify the Company's commodity price exposure and add stability during periods of market volatility, hedges have been layered on approximately 30 percent of Bonterra's expected crude oil and natural gas production through Q2 2024. Through the next nine months, Bonterra has secured the following risk management contracts:
- WTI prices between
$50.00 USD to$93.75 USD per bbl on approximately 2,368 bbls per day; and - Natural gas prices between
$2.15 to$3.75 per GJ on approximately 11,172 GJ per day.
Bonterra believes that through continued execution of its focused business strategy along with the ongoing development of its high-quality, oil-weighted asset base, the Company will be ideally positioned to generate sustainable profitability that can drive positive returns for shareholders.
About Bonterra
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1 Non-IFRS measure. See advisories later in this press release. |
Cautionary Statements
This summarized news release should not be considered a suitable source of information for readers who are unfamiliar with
Non-IFRS and Other Financial Measures
Throughout this release the Company uses the terms "funds flow", "free funds flow", "net debt", "field netback" and "cash netback" to analyze operating performance, which are not standardized measures recognized under IFRS and do not have a standardized meaning prescribed by IFRS. These measures are commonly utilized in the oil and gas industry and are considered informative by management, shareholders and analysts. These measures may differ from those made by other companies and accordingly may not be comparable to such measures as reported by other companies.
The Company defines funds flow as funds provided by operations including proceeds from sale of investments and investment income received excluding effects of changes in non-cash working capital items and decommissioning expenditures settled. Free funds flow is defined as funds flow less dividends paid to shareholders, capital and decommissioning expenditures settled. Net debt is defined as long-term subordinated term debt, subordinated debentures and bank debt plus working capital deficiency (current liabilities less current assets). Field netback is defined as revenue and realized risk management contract gain (loss) minus royalties and operating expenses divided by total BOEs for the period. Cash netback is defined as Field netback less interest expense, general and administrative expense and current income tax expense divided by total BOEs for the period. EBITDA is defined as net earnings excluding deferred consideration, finance costs, provision for current and deferred taxes, depletion and depreciation, share-option compensation, gain or loss on sale of assets and unrealized gain or loss on risk management contracts. Net debt to EBITDA ratio is defined as net debt at the end of the period divided by EBITDA for the trailing twelve months.
Forward Looking Information
Certain statements contained in this release include statements which contain words such as "anticipate", "could", "should", "expect", "seek", "may", "intend", "likely", "will", "believe" and similar expressions, relating to matters that are not historical facts, and such statements of our beliefs, intentions and expectations about development, results and events which will or may occur in the future, constitute "forward-looking information" within the meaning of applicable Canadian securities legislation and are based on certain assumptions and analysis made by us derived from our experience and perceptions. Forward-looking information in this release includes, but is not limited to: expansion and other development trends of the oil and gas industry; business strategy and outlook; and expansion and growth of our business and operations.
All such forward-looking information is based on certain assumptions and analyses made by us in light of our experience and perception of historical trends, current conditions and expected future developments, as well as other factors we believe are appropriate in the circumstances. The risks, uncertainties, and assumptions are difficult to predict and may affect operations, and may include, without limitation: foreign exchange fluctuations; equipment and labour shortages and inflationary costs; general economic conditions; industry conditions; changes in applicable environmental, taxation and other laws and regulations as well as how such laws and regulations are interpreted and enforced; the ability of oil and natural gas companies to raise capital or maintain its syndicated bank facility; the effect of weather conditions on operations and facilities; the existence of operating risks; volatility of oil and natural gas prices; oil and gas product supply and demand; risks inherent in the ability to generate sufficient cash flow from operations to meet current and future obligations; increased competition; stock market volatility; opportunities available to or pursued by us; and other factors, many of which are beyond our control.
The forward-looking information contained herein is expressly qualified by this cautionary statement.
Frequently recurring terms
Bonterra uses the following frequently recurring terms in this press release: "WTI" refers to West Texas Intermediate, a grade of light sweet crude oil used as benchmark pricing in
Numerical Amounts
The reporting and the functional currency of the Company is the Canadian dollar.
The TSX does not accept responsibility for the accuracy of this release.
SOURCE
© Canada Newswire, source