\nRevised 2025<\/p>\n
\nForecast<\/p>\n<\/td>\n
\n% Increase from<\/p>\n
\nFiscal Year 2024<\/p>\n<\/td>\n<\/tr>\n
\n\u00a0<\/p>\n<\/td>\n
\n\u00a0<\/p>\n<\/td>\n
\n\u00a0<\/p>\n<\/td>\n<\/tr>\n
\nFull Year average production<\/p>\n<\/td>\n
\n4,000 to 4,400 boepd<\/p>\n<\/td>\n
\n15% to 27%<\/p>\n<\/td>\n<\/tr>\n
\nRevenue(1)<\/sup><\/p>\n<\/td>\n \nUS$61 million to US$65 million<\/p>\n<\/td>\n \n4% to 11%<\/p>\n<\/td>\n<\/tr>\n \nAdjusted EBITDA(2)<\/sup><\/p>\n<\/td>\n \nUS$46 million to US$50 million<\/p>\n<\/td>\n \n4% to 14%<\/p>\n<\/td>\n<\/tr>\n<\/table>\n \n(1)<\/p>\n<\/td>\n \nAssumptions include forecasted pricing for September – December 2025 of WTI US $64\/bbl, $3.70 Henry Hub and NGL pricing of $26\/boe and includes the impact of the Company\u2019s existing hedges.<\/p>\n<\/td>\n<\/tr>\n \n(2)<\/p>\n<\/td>\n \nAdjusted EBITDA is considered a non-GAAP measure. Refer to the section entitled \u201cNon-GAAP Measures\u201d of this news release.<\/p>\n<\/td>\n<\/tr>\n<\/table>\n \nThe average production, revenue and Adjusted EBITDA guidance show significant growth from 2024 even though this guidance has been revised lower from the Company\u2019s previous guidance due to several factors. The first factor is lower than expected oil prices, which have averaged less than the $70\/bbl price used in our original guidance from early January 2025, when oil was at $78\/bbl. Also, the four wells that were planned to come on production during the fourth quarter are delayed due to a drill pipe failure. After the Barnes 6-31-3H well was drilled to total depth, the drill pipe failure caused the drilling assembly to become stuck in the wellbore. Attempts to recover the drilling assembly were unsuccessful. As a result, the well is currently being redrilled. This has caused a delay in the fracture stimulations of all four wells since they are located in the same area. While this incident will not impact the ultimate productivity of the well, the delay in the start of production from the new wells has caused us to adjust our original forecast.<\/p>\n \nThe Company expects annual capital expenditures paid during the year to be in the range of US$55 million to US$58 million, which is higher than originally forecasted due to the redrill, weather issues, and cost increases in 2025. Net debt is forecasted to be between US$46 million and US$48 million, which is higher than previously forecast, mainly due to the timing of the wells. We expect to generate cash flow from production, including the four new wells, to make debt paydowns of $8 million to $10 million in the first quarter of 2026.<\/p>\n Operations Update<\/b><\/p>\n \nThe Barnes 6-31-2H well was successfully and safely drilled under budget, per field estimates. Once the redrill of the Barnes 6-31-3H well is completed, the Company will begin completion operations on the two Barnes wells along with the Velin 12-9 and 12-10 wells that have already been drilled.<\/p>\n \nThe four Lovina wells that were completed earlier this year are still producing at a higher oil rate of 80% and declining at lower rates than our other wells.<\/p>\n \nThe Forguson 17-20-3H well, which is located on the east side of our property is still increasing production as frack fluid is being recovered. While only 3.8 percent of the frack fluid has been recovered, production from the well has increased by 21 percent since our last update. On average, our wells have achieved their peak production rate by the time 7%-10% of the fracture stimulation fluid has been recovered. The well is currently averaging about 195 Barrels of oil equivalent per day, with 106 barrels being oil.<\/p>\n \nWolf Regener, President and CEO, commented, \u201cIt is unfortunate and disappointing when a single component failure impacts the Company\u2019s drilling program. We have not been forced to redrill a well in over 11 years. We are not happy with the delay it has caused in completing the four wells, but I am glad that it won\u2019t affect the ultimate productivity of the well. These wells are now expected to come on production in December and thus will have the biggest impact on production in the first quarter of 2026. We expect to achieve a record production exit rate, which sets the Company up for a strong 2026 with further success to grow from.<\/p>\n \nOn the Lovina wells, we are happy to see that they are declining at lower rates than other wells in our field. This is what we were predicting given the higher percentage oil rates from the wells, which are also expected to lead to higher netbacks for the Company.<\/p>\n \nThe continued improvement in the production rates of the Forguson well is also encouraging. As a reminder, the Forguson well and the 3,000 net acres associated with it in the eastern part of the field are not part of our reserve report.\u201d<\/p>\n About Kolibri Global Energy Inc.<\/b><\/p>\n Kolibri Global Energy Inc. is a North American energy company focused on finding and exploiting energy projects in oil and gas. Through various subsidiaries, the Company owns and operates energy properties in the United States. The Company continues to utilize its technical and operational expertise to identify and acquire additional projects in oil and gas. The Company’s shares are traded on the Toronto Stock Exchange under the stock symbol KEI and on the NASDAQ under the stock symbol KGEI.<\/i><\/p>\n Product Type Disclosure<\/b><\/p>\n \nThis news release includes references to sales volumes of “oil”, “natural gas”, and \u201cbarrels of oil equivalent\u201d or \u201cBOEs\u201d. \u201cOil\u201d refers to light crude oil and medium crude oil combined, and “natural gas” refers to shale gas, in each case as defined by NI 51-101. Production from our wells, primarily disclosed in this news release in BOEs, consists of mainly oil and associated wet gas. The wet gas is delivered via gathering system and then pipelines to processing plants where it is treated and sold as natural gas and NGLs.<\/p>\n Non-GAAP Measures<\/b><\/p>\n \nAdjusted EBITDA is not a measure recognized under Canadian Generally Accepted Accounting Principles (“GAAP<\/b>“) and does not have any standardized meaning prescribed by IFRS. Management of the Company believes that Adjusted EBITDA is relevant for evaluating returns on the Company’s project as well as the performance of the enterprise as a whole. Adjusted EBITDA may differ from similar computations as reported by other similar organizations and, accordingly, may not be comparable to similar non-GAAP measures as reported by such organizations. Adjusted EBITDA should not be construed as an alternative to net income, cash flows related to operating activities, working capital, or other financial measures determined in accordance with IFRS as an indicator of the Company’s performance.<\/p>\n \nAn explanation of how Adjusted EBITDA provides useful information to an investor and the purposes for which the Company\u2019s management uses Adjusted EBITDA is set out in the management’s discussion and analysis under the heading \u201cNon-GAAP Measures\u201d which is available under the Company’s profile at www.sedarplus.ca<\/a> and is incorporated by reference into this news release.<\/p>\n \nAdjusted EBITDA is calculated as net income before interest, taxes, depletion and depreciation and other non-cash and non-operating gains and losses. The Company considers this a key measure as it demonstrates its ability to generate cash from operations necessary for future growth excluding non-cash items, gains and losses that are not part of the normal operations of the Company and financing costs.<\/p>\n \nThe following is the reconciliation of the non-GAAP measure Adjusted EBITDA to the comparable financial measures disclosed in the Company\u2019s financial statements:<\/p>\n (US $000)<\/i><\/p>\n<\/td>\n \nThree months ended<\/p>\n \nJune 30,<\/p>\n<\/td>\n \nSix months ended<\/p>\n \nJune 30,<\/p>\n<\/td>\n<\/tr>\n \n2025<\/p>\n<\/td>\n \n2024<\/p>\n<\/td>\n \n2025<\/p>\n<\/td>\n \n2024<\/p>\n<\/td>\n<\/tr>\n \nNet income<\/p>\n<\/td>\n \n2,853<\/p>\n<\/td>\n \n4,061<\/p>\n<\/td>\n \n8,618<\/p>\n<\/td>\n \n7,406<\/p>\n<\/td>\n<\/tr>\n \nIncome tax expense<\/p>\n<\/td>\n \n936<\/p>\n<\/td>\n \n1,451<\/p>\n<\/td>\n \n\u00a0<\/p>\n<\/td>\n \n2,917<\/p>\n<\/td>\n \n2,642<\/p>\n<\/td>\n<\/tr>\n \nDepletion and depreciation<\/p>\n<\/td>\n \n3,516<\/p>\n<\/td>\n \n3,700<\/p>\n<\/td>\n \n7,579<\/p>\n<\/td>\n \n7,594<\/p>\n<\/td>\n<\/tr>\n \nAccretion<\/p>\n<\/td>\n \n73<\/p>\n<\/td>\n \n44<\/p>\n<\/td>\n \n124<\/p>\n<\/td>\n \n89<\/p>\n<\/td>\n<\/tr>\n \nInterest expense<\/p>\n<\/td>\n \n640<\/p>\n<\/td>\n \n813<\/p>\n<\/td>\n \n1,336<\/p>\n<\/td>\n \n1,728<\/p>\n<\/td>\n<\/tr>\n \nUnrealized (gain) loss on commodity contracts<\/p>\n<\/td>\n \n(490)<\/p>\n<\/td>\n \n(445)<\/p>\n<\/td>\n \n(455)<\/p>\n<\/td>\n \n470<\/p>\n<\/td>\n<\/tr>\n \nShare based compensation<\/p>\n<\/td>\n \n488<\/p>\n<\/td>\n \n411<\/p>\n<\/td>\n \n725<\/p>\n<\/td>\n \n539<\/p>\n<\/td>\n<\/tr>\n \nInterest income<\/p>\n<\/td>\n \n(8)<\/p>\n<\/td>\n \n–<\/p>\n<\/td>\n \n(16)<\/p>\n<\/td>\n \n–<\/p>\n<\/td>\n<\/tr>\n \nOther income<\/p>\n<\/td>\n \n(325)<\/p>\n<\/td>\n \n(1)<\/p>\n<\/td>\n \n(326)<\/p>\n<\/td>\n \n(60)<\/p>\n<\/td>\n<\/tr>\n \nForeign currency loss (gain)<\/p>\n<\/td>\n \n(2)<\/p>\n<\/td>\n \n2<\/p>\n<\/td>\n \n(1)<\/p>\n<\/td>\n \n2<\/p>\n<\/td>\n<\/tr>\n \nAdjusted EBITDA<\/p>\n<\/td>\n \n7,681<\/p>\n<\/td>\n \n10,036<\/p>\n<\/td>\n \n20,501<\/p>\n<\/td>\n \n20,410<\/p>\n<\/td>\n<\/tr>\n<\/table>\n Caution Regarding Forward-Looking Information<\/i><\/b><\/p>\n Certain statements contained in this news release constitute “forward-looking information” as such term is used in applicable Canadian securities laws and \u201cforward-looking statements\u201d within the meaning of United States securities laws (collectively, \u201cforward looking information\u201d), including statements regarding the timing of and expected results from planned wells development (including the timing of the four wells planned to come on production), projected average production, revenue and Adjusted EBITDA for 2025, anticipated productivity of the Barnes 6-31-3H well, expected annual capital expenditures, forecasted net debt, anticipated increases to netbacks and the anticipated use of cash flow from production to make debt paydowns. Forward-looking information is based on plans and estimates of management and interpretations of data by the Company’s technical team at the date the data is provided and is subject to several factors and assumptions of management, including forecasted pricing in 2025 of WTI US$64\/bbl, US$3.70 Henry Hub and NGL pricing of US$26\/boe, that indications of early results are reasonably accurate predictors of the prospectiveness of the shale intervals, that required regulatory approvals will be available when required, that no unforeseen delays, unexpected geological or other effects, including flooding and extended interruptions due to inclement or hazardous weather conditions, equipment failures, permitting delays or labor or contract disputes are encountered, that the necessary labor and equipment will be obtained, that the development plans of the Company and its co-venturers will not change, that the offset operator\u2019s operations will proceed as expected by management, that the demand for oil and gas will be sustained, that the price of oil will be sustained or increase, that the Company will continue to be able to access sufficient capital through cash flow, debt, financings, farm-ins or other participation arrangements to maintain its projects, and that global economic conditions will not deteriorate in a manner that has an adverse impact on the Company’s business, its ability to advance its business strategy and the industry as a whole. Forward-looking information is subject to a variety of risks and uncertainties and other factors that could cause plans, estimates and actual results to vary materially from those projected in such forward-looking information. Factors that could cause the forward-looking information in this news release to change or to be inaccurate include, but are not limited to, the risk that any of the assumptions on which such forward looking information is based vary or prove to be invalid, including that the Company or its subsidiaries is not able for any reason to obtain and provide the information necessary to secure required approvals or that required regulatory approvals are otherwise not available when required, that unexpected geological results are encountered, that equipment failures, permitting delays, labor or contract disputes or shortages of equipment, labor or materials are encountered, the risks associated with the oil and gas industry (e.g. operational risks in development, exploration and production; delays or changes in plans with respect to exploration and development projects or capital expenditures; the uncertainty of reserve and resource estimates and projections relating to production, costs and expenses, and health, safety and environmental risks, including flooding and extended interruptions due to inclement or hazardous weather conditions), the risk of commodity price and foreign exchange rate fluctuations, that the offset operator\u2019s operations have unexpected adverse effects on the Company\u2019s operations, that completion techniques require further optimization, that production rates do not match the Company\u2019s assumptions, that very low or no production rates are achieved, that the price of oil will decline, that the Company is unable to access required capital, that occurrences such as those that are assumed will not occur, do in fact occur, and those conditions that are assumed will continue or improve, do not continue or improve, and the other risks and uncertainties applicable to exploration and development activities and the Company’s business as set forth in the Company’s management discussion and analysis and its annual information form, both of which are available for viewing under the Company’s profile at <\/i>www.sedar.com<\/a>, any of which could result in delays, cessation in planned work or loss of one or more leases and have an adverse effect on the Company and its financial condition. The Company undertakes no obligation to update these forward-looking statements, other than as required by applicable law.<\/i><\/p>\n Caution Regarding Future-Oriented Financial Information and Financial Outlook<\/i><\/b><\/p>\n This news release may contain information deemed to be \u201cfuture-oriented financial information\u201d or a \u201cfinancial outlook\u201d (collectively, \u201cFOFI\u201d) within the meaning of applicable securities laws. The FOFI has been prepared by management to provide an outlook of the Company\u2019s activities and results and may not be appropriate for other purposes. The FOFI has been prepared based on a number of assumptions including the assumptions discussed above under \u201cCaution Regarding Forward-Looking Information\u201d. The actual results of operations of the Company and the resulting financial results may vary from the amounts set forth herein, and such variations may be material. The Company and management believe that the FOFI has been prepared on a reasonable basis, reflecting management\u2019s best estimates and judgments. FOFI contained in this news release was made as of the date of this news release and the Company disclaims any intention or obligations to update or revise any FOFI contained in this news release, whether as a result of new information, future events or otherwise, unless required pursuant to applicable law.<\/i><\/p>\n View source version on businesswire.com: <\/span>https:\/\/www.businesswire.com\/news\/home\/20251006883789\/en\/<\/a><\/span><\/p>\n For further information, contact: KEYWORDS:<\/b> California North America United States Ireland United Kingdom Europe<\/p>\n INDUSTRY KEYWORDS:<\/b> Energy Natural Resources Other Natural Resources Oil\/Gas<\/p>\n\n \n \n \n \n \n \n \n \n \n \n
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\n<\/b>
Wolf E. Regener +1 (805) 484-3613
\n
Email: wregener@kolibrienergy.com
\n<\/a>
<\/span>Website: www.kolibrienergy.com<\/a><\/p>\n
![\"Logo\"](\"https:\/\/mms.businesswire.com\/media\/20251006883789\/en\/1285787\/3\/Kolibri_Logo.jpg\"){kind=logo}
<\/td>\n<\/tr>\n