2 weeks Ago By [email protected] (MENAFN)
Canacol Energy Ltd Gross Conventional Natural Gas, Light/Medium/Heavy Crude Oil Reserves and Deemed Volumes Summary (1)(5) Highlights Conventional Natural Gas and Light/Medium/Heavy Crude Oil Proved + Probable Reserves and Deemed Volumes (“2P”): Conventional Natural Gas and Light/Medium/Heavy Crude Oil Total Proved Reserves and Deemed Volumes (“1P”): Conventional Natural Gas and Light/Medium/Heavy Crude Oil Total Proved + Probable + Possible Reserves and Deemed Volumes (“3P”): Ravi Sharma, COO said,“In 2024 we added 50 Bcfe of 2P reserves and deemed volumes, for a Reserves Replacement Ratio of 85%. We were able to drill Merengon (Natilla exploration well) to the top of the primary target CDO interval, but due to technical difficulties, had to do a second sidetrack through the lower Porquero. We are currently casing the secondary gas bearing Porquero section and preparing to drill and complete the primary CDO target shortly.
” Discussion of Year Ended December 31, 2024 Reserves Report During the year ended December 31, 2024, the Corporation recorded increases in certain reserve categories due to both new gas discoveries and positive technical revisions of existing producing gas fields. The following tables summarize information from the independent reserves report prepared by Boury Global Energy Consultants Ltd. (“BGEC”) effective December 31, 2024 (the“BGEC 2024 report”).
The BGEC 2024 report covers 100% of the Corporation's conventional natural gas and light/medium/heavy oil reserves and deemed volumes. The BGEC 2024 report was prepared in accordance with definitions, standards and procedures contained in the Canadian Oil and Gas Evaluation Handbook (“COGE Handbook”) and National Instrument NI 51-101, Standards of Disclosure for Oil and Gas Activities (“NI 51-101”). Additional reserve information as required under NI 51-101 is included in the Corporation's Annual Information Form, which will be filed on SEDAR by March 31, 2025.
Canacol Gross Natural Gas, Light/Medium/Heavy Crude Oil Reserves and Deemed Volumes for the Year Ended December 31, 2024 (1) 5-Year Gas and Oil Price Forecasts – BGEC Report December 31, 2024 (1) Conventional Natural Gas, Light/Medium/Heavy Crude Oil Reserves, and Deemed Volumes Net Present Value Before & After Tax Summary (1) Reserve Life Index (“RLI”) (1)(2) Year Ended December 31, 2024 Canacol Gross Reserves and Deemed Volumes Reconciliation (1) 1P Reserves Metrics Reconciliation – Canacol Working Interest before Royalty (1)(2) 2P Reserves Metrics Reconciliation – Canacol Working Interest before Royalty (1)(2) 3P Natural Gas Reserves Metrics Reconciliation – Canacol Working Interest before Royalty (1)(2) The recovery and reserve and deemed volume estimates of conventional natural gas and light/medium/heavy crude oil are estimates only. There is no guarantee that the estimated reserves and deemed volumes will be recovered, and actual reserves of conventional natural gas and light/medium/heavy crude oil and deemed volumes may prove to be greater than, or less than, the estimates provided. About Canacol Canacol is a natural gas and oil exploration and production company with operations focused in Colombia.
The Corporation's common stock trades on the Toronto Stock Exchange, the OTCQX in the United States of America, and the Colombia Stock Exchange under ticker symbol CNE, CNNEF, and CNE.C, respectively. Forward-Looking Information and Statements 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 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. Use of Non-IFRS Financia l 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 (used) provided by operating activities before changes in non-cash working capital, settlement of a litigation settlement liability and decommissioning obligation expenditures. The Corporation considers 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 (used) 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.
The reserves evaluation, effective December 31, 2024, was conducted by the Corporation's independent reserves evaluator Boury Global Energy Consultants Ltd. (“BGEC”) and are in accordance with National Instrument 51-101 - Standards of Disclosure for Oil and Gas Activities. The reserves are provided on a Canacol Gross basis in units of thousands of cubic feet (“MMcf”) and thousands of barrels of oil equivalent (“MBOE”) using a forecast price deck in US dollars.
The estimated values may or may not represent the fair market value of the reserve estimates. "Gross" in relation to the Corporation's interest in production or reserves is its working interest (operating or non-operating) share before deduction of royalties and without including any royalty interests of the Corporation; "Net" in relation to the Corporation's interest in production or reserves is its working interest (operating or non-operating) share after deduction of royalty obligations, plus its royalty interest in production or reserves; “Proved Developed Producing Reserves" are those reserves that are expected to be recovered from completion intervals open at the time of the estimate. These reserves may be currently producing or, if shut-in, they must have previously been on production, and the date of resumption of production must be known with reasonable certainty.
“Proved reserves” are those reserves that can be estimated with a high degree of certainty to be recoverable. It is likely that the actual remaining quantities recovered will exceed the estimated proved reserves; “Probable reserves” are those additional reserves that are less certain to be recovered than proved reserves. It is equally likely that the actual remaining quantities recovered will be greater or less than the sum of the estimated proved plus probable reserves; “Possible reserves” means those additional reserves that are less certain to be recovered than probable reserves.
It is unlikely that the actual remaining quantities recovered will exceed the sum of the estimated proved plus probable plus possible reserves; “Deemed Volumes” refer to COGEH Section 3.9.4.
8 – Assigning Reserves, and refer to the economic interest method which is used for Risked service contracts where, for volumes produced, the Corporation does not have a direct interest but represents reserves attributable to the Corporation. By definition, these volumes are calculated as the production revenue divided by the tariff price and are considered additive to volumes certified as reserves. Under the terms of this risked Service Agreement, these calculated volumes correspond to actual volumes produced.
BOE and CFE Conversions -“BOE” barrel of oil equivalent or“CFE” cubic feet of gas equivalent is derived by converting natural gas to oil or vice versa in the ratio of 5.7 Mcf of natural gas to one bbl of oil. A BOE or CFE conversion ratio of 5.
7 Mcf to 1 bbl is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead. 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 5.7:1, utilizing a conversion on a 5.
7:1 basis may be misleading as an indication of value. In this news release, the Corporation has expressed BOE using the Colombian conversion standard of 5.7 Mcf: 1 bbl required by the Ministry of Mines and Energy of Colombia.
“PDP” means Proved Developed Producing “1P” means Total Proved “2P” means Total Proved + Probable “3P” means Total Proved + Probable + Possible PDP Reserves replacement ratio: Ratio of reserve additions to production, as reported in financial statements during the fiscal year ended December 31, excluding acquisitions and dispositions on a Proved Developed Producing basis. 1P Reserves replacement ratio: Ratio of reserve additions to production, as reported in financial statements during the fiscal year ended December 31, excluding acquisitions and dispositions on a Total Proved basis. 2P Reserves replacement ratio: Ratio of reserve additions to production, as reported in financial statements during the fiscal year ended December 31, excluding acquisitions and dispositions on a Total Proved + Probable basis.
Finding and development costs per thousand cubic feet (Mcf) represent exploration and development costs incurred per Mcf of Total Proved + Probable reserves added during the year. The Corporation, industry analysts, and investors use such metrics to measure a Corporation's ability to establish a long-term trend of adding reserves at a reasonable cost. Finding, development and acquisition costs per thousand cubic feet (Mcf) represent property acquisition, exploration, and development costs incurred per Mcf of Total Proved + Probable reserves added during the year.
The Corporation, industry analysts, and investors use such metrics to measure a Corporation's ability to establish a long-term trend of adding reserves at a reasonable cost. With the finding and development costs, the aggregate of the exploration and development costs incurred in the most recent financial year and the change during that year in estimated future development costs generally will not reflect total finding and development costs related to reserve additions for that year. Natural gas recycle ratio is calculated by dividing natural gas netback by finding and development costs.
“RLI” Reserve Life Index is calculated by dividing the applicable reserves category by the annualized fourth quarter production. This press release contains a number of oil and gas metrics, including F&D, FD&A, reserve replacement and RLI, which do not have standardized meanings or standard methods of calculation and therefore such measures may not be comparable to similar measures used by other companies. Such metrics have been included herein to provide readers with additional measures to evaluate the Corporation's performance; however, such measures are not reliable indicators of the future performance of the Corporation and future performance may not compare to the performance in previous periods.
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