Canacol Energy Ltd. Reports Net Income of $13.9 Million For The Second Quarter of 2025

CALGARY, Alberta, Aug. 07, 2025 (GLOBE NEWSWIRE) -- Canacol Energy Ltd. (“Canacol” or the “Corporation”) (TSX:CNE; OTCQX:CNNEF; BVC:CNEC) is pleased to report its financial and operating results for the three and six months ended June 30, 2025. Dollar amounts are expressed in United States dollars, with the exception of Canadian dollar unit prices (“C$”) where indicated and otherwise noted.

Highlights for the three and six months ended June 30, 2025.

• The Corporation’s natural gas and liquefied natural gas (“LNG”) operating netback decreased 4% to $5.11 per Mcf for the three months ended June 30, 2025, compared to $5.34 per Mcf for the same period in 2024. The decrease is mainly due to an increase in operating expenses on a per Mcf basis as a result of fixed operating expenses over lower sales volume. The Corporation’s natural gas and LNG operating netback increased 4% to $5.30 per Mcf for the six months ended June 30, 2025, compared to $5.12 per Mcf for the same period in 2024. The increase is due to an increase in average sales prices, offset by an increase in operating expenses on a per Mcf basis.
• Adjusted EBITDAX decreased 35% and 23% to $47.4 million and $103.6 million for the three and six months ended June 30, 2025, respectively, compared to $73.2 million and $134.2 million for the same periods in 2024, respectively. The decrease is mainly due to a decrease in realized contractual natural gas and LNG sales volumes.
• Adjusted funds from operations decreased 35% and 23% to $36.9 million and $76.2 million for the three and six months ended June 30, 2025, respectively, compared to $57.1 million and $99.3 million for the same periods in 2024, respectively, mainly due to a decrease in EBITDAX.
• Total revenues, net of royalties and transportation expenses for the three and six months ended June 30, 2025 decreased 27% and 17% to $64.8 million and $137.5 million, respectively, compared to $88.3 million and $166.0 million for the same periods in 2024, respectively, mainly due to a decrease in realized natural gas and LNG sales volumes.
• Realized contractual natural gas sales volume decreased 25% and 20% to 119.0 MMcfpd and 123.8 MMcfpd for the three and six months ended June 30, 2025, respectively, compared to 158.5 MMcfpd and 154.5 MMcfpd for the same periods in 2024, respectively.
• The Corporation realized net income of $13.9 million and $45.7 million for the three and six months ended June 30, 2025, respectively, compared to a net loss of $21.3 million and $17.6 million for the same periods in 2024, respectively. The increase in net income is the result of recognizing a non-cash deferred income tax recovery of $14.1 million and $33.6 million for the three and six months ended June 30, 2025, respectively, compared to a non-cash deferred income tax expense of $42.6 million and $43.1 million for the same periods in 2024, respectively.
• Net cash capital expenditures for the three and six months ended June 30, 2025 were $57.1 million and $107.5 million, respectively, compared to $33.9 million and $69.7 million for the same periods in 2024, respectively. The increase is mainly related to the cost of drilling the Natilla-2 exploration well.
• As at June 30, 2025, the Corporation had $37.0 million in cash and cash equivalents and $20.9 million in working capital deficit.

Outlook

The Corporation remains focused on completing its exploration and development drilling and workover programs, and the installation of additional compression, for the remainder of 2025. One new successful exploration well, Borbon-1, and one new successful appraisal well, Fresa-4, were drilled in June 2025. The Corporation is also completing the drilling of the Palomino-1 exploration well located in the Sucre Norte area as of the date of this release.

At the end of July 2025, the Borbon-1 and Zamia-1 exploration wells, located in the Sucre Norte area, were tied into the permanent production facilities at Jobo, with each currently producing approximately 8 MMcfpd. The successful Fresa-4 appraisal well was also brought onto production at the end of July 2025 and is currently producing at approximately 9 MMcfpd. Once completed, the Palomino-1 exploration well is anticipated to be brought on to production at a rate of between 8 and 10 MMcfpd by mid-August 2025. Current natural gas sales are approximately 138 MMcfpd.

Sustainability

During the quarter ended June 30, 2025, the Corporation presented its 2024 ESG and TCFD Reports. Both reports are available on the Corporation’s website at www.canacolenergy.com.

Executive Management Change

The Corporation announces that Mr. William Satterfield, Senior Vice President of Exploration, tendered his resignation effective August 7, 2025. The Board of Directors of the Corporation wish to thank Mr. Satterfield for his dedication and contributions to Canacol over the past four years, and wish him well in his future personal and professional endeavors.

FINANCIAL & OPERATING HIGHLIGHTS

(in United States dollars (tabular amounts in thousands) except as otherwise noted)

This press release should be read in conjunction with the Corporation’s interim condensed consolidated financial statements and related Management’s Discussion and Analysis (“MD&A”). The Corporation has filed its interim condensed consolidated financial statements and related MD&A as at and for the six months ended June 30, 2025 with Canadian securities regulatory authorities. These filings are available for review on SEDAR+ at www.sedarplus.ca.

Canacol is a natural gas exploration and production company with operations focused in Colombia. The Corporation’s shares are traded on the Toronto Stock Exchange under the symbol CNE, the OTCQX in the United States of America under the symbol CNNEF, the Bolsa de Valores de Colombia under the symbol CNEC.

This press release contains certain forward-looking statements within the meaning of applicable securities law. Forward-looking statements are frequently characterized by words such as “plan”, “expect”, “project”, “target”, “intend”, “believe”, “anticipate”, “estimate” and other similar words, or statements that certain events or conditions “may” or “will” occur, including without limitation statements relating to estimated production rates from the Corporation’s properties and intended work programs and associated timelines. Forward-looking statements are based on the opinions and estimates of management at the date the statements are made and are subject to a variety of risks and uncertainties and other factors that could cause actual events or results to differ materially from those projected in the forward-looking statements. The Corporation cannot assure that actual results will be consistent with these forward looking statements. They are made as of the date hereof and are subject to change and the Corporation assumes no obligation to revise or update them to reflect new circumstances, except as required by law. Information and guidance provided herein supersedes and replaces any forward looking information provided in prior disclosures. Prospective investors should not place undue reliance on forward looking statements. These factors include the inherent risks involved in the exploration for and development of crude oil and natural gas properties, the uncertainties involved in interpreting drilling results and other geological and geophysical data, fluctuating energy prices, the possibility of cost overruns or unanticipated costs or delays and other uncertainties associated with the oil and gas industry. Other risk factors could include risks associated with negotiating with foreign governments as well as country risk associated with conducting international activities, and other factors, many of which are beyond the control of the Corporation. Other risks are more fully described in the Corporation’s most recent Management Discussion and Analysis (“MD&A”) and Annual Information Form, which are incorporated herein by reference and are filed on SEDAR+ at www.sedarplus.ca. Average production figures for a given period are derived using arithmetic averaging of fluctuating historical production data for the entire period indicated and, accordingly, do not represent a constant rate of production for such period and are not an indicator of future production performance. Detailed information in respect of monthly production in the fields operated by the Corporation in Colombia is provided by the Corporation to the Ministry of Mines and Energy of Colombia and is published by the Ministry on its website; a direct link to this information is provided on the Corporation’s website. References to “net” production refer to the Corporation’s working-interest production before royalties.

Use of Non-IFRS Financial Measures - Such supplemental measures should not be considered as an alternative to, or more meaningful than, the measures as determined in accordance with IFRS as an indicator of the Corporation’s performance, and such measures may not be comparable to that reported by other companies. This press release also provides information on adjusted funds from operations. Adjusted funds from operations is a measure not defined in IFRS. It represents cash provided (used) by operating activities before changes in non-cash working capital and the settlement of decommissioning obligation, adjusted for non-recurring charges. The Corporation considers adjusted funds from operations a key measure as it demonstrates the ability of the business to generate the cash flow necessary to fund future growth through capital investment and to repay debt. Adjusted funds from operations should not be considered as an alternative to, or more meaningful than, cash provided by operating activities as determined in accordance with IFRS as an indicator of the Corporation’s performance. The Corporation’s determination of adjusted funds from operations may not be comparable to that reported by other companies. For more details on how the Corporation reconciles its cash provided by operating activities to adjusted funds from operations, please refer to the “Non-IFRS Measures” section of the Corporation’s MD&A. Additionally, this press release references Adjusted EBITDAX and operating netback measures. Adjusted EBITDAX is defined as consolidated net income adjusted for interest, income taxes, depreciation, depletion, amortization, exploration expenses and other similar non-recurring or non-cash charges. Operating netback is a benchmark common in the oil and gas industry and is calculated as total natural gas, LNG and petroleum sales, net transportation expenses, less royalties and operating expenses, calculated on a per barrel of oil equivalent basis of sales volumes using a conversion. Operating netback is an important measure in evaluating operational performance as it demonstrates field level profitability relative to current commodity prices. Adjusted EBITDAX and operating netback as presented do not have any standardized meaning prescribed by IFRS and therefore may not be comparable with the calculation of similar measures for other entities.

Operating netback is defined as revenues, net transportation expenses less royalties and operating expenses.

Realized contractual sales is defined as natural gas and LNG produced and sold plus income received from nominated take-or-pay contracts without the actual delivery of natural gas or LNG and the expiry of the customers’ rights to take the deliveries.

Net cash capital expenditures is defined as capital expenditures net of dispositions, excluding non-cash costs and adjustments such as the addition of right-of-use leased assets and change in decommissioning obligations.

The Corporation’s LNG sales account for less than one percent of the Corporation’s total realized contractual natural gas and LNG sales.

Boe Conversion - The term “boe” is used in this news release. Boe may be misleading, particularly if used in isolation. A boe conversion ratio of cubic feet of natural gas to barrels oil equivalent is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead. In this news release, we have expressed boe using the Colombian conversion standard of 5.7 Mcf: 1 bbl required by the Ministry of Mines and Energy of Colombia. As the value ratio between natural gas and crude oil based on the current prices of natural gas and crude oil is significantly different from the energy equivalency of 5.7 Mcf:1, utilizing a conversion on a 5.7 Mcf:1 basis may be misleading as an indication of value.

For further information please contact:        

Investor Relations
South America: +571.621.1747 IR-SA@canacolenergy.com
Global: +1.403.561.1648 IR-GLOBAL@canacolenergy.com         

http://www.canacolenergy.com

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