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Kolibri Global Energy Inc. Emery 17-3H Well Averaged Over 700 BOEPD In Last 10 Days of Production
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Kolibri Global Energy Inc. provided updates on three wells in the Tishomingo field, Oklahoma. The Emery 17-3H well is averaging 704 BOEPD, outperforming both company forecasts and previous wells. The Brock 9-3H and Glenn 16-3H wells have also been stimulated and are expected to commence flowback soon. CEO Wolf Regener highlighted the strong early results of the Emery 17-3H well, indicating potential for better-than-expected initial production rates compared to prior assessments.
Positive
Emery 17-3H well averaging 704 BOEPD, exceeding forecasts of 388 BOEPD (Reserve Report IP30) and 472 BOEPD (Management IP30).
Positive early performance indicates potential for higher IP30 rates than previously estimated.
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THOUSAND OAKS, Calif.--(BUSINESS WIRE)--
Kolibri Global Energy Inc. (the “Company” or “KEI”) (TSX: KEI, OTCQX: KGEIF) is providing an update on the Emery 17-3H well (98.725% working interest), the Brock 9-3H well (100% working interest) and the Glenn 16-3H well (100% working interest), in its Tishomingo field in Oklahoma.
Emery 17-3H Well
The Emery 17-3H well has averaged about 704 Barrels of oil equivalent per day (“BOEPD”) (547 Barrels of oil per day (“BOPD”)) for the last ten days as the well has been flowing back the completion stimulation fluid.
Wolf Regener, President and CEO, commented, “We are extremely pleased about the early performance of the Emery 17-3H well. These strong early results are occurring while the well is still flowing up casing as the tubing is scheduled to be installed in the coming weeks.
To put the well performance in perspective, the forecasted 30-day proved curve case initial production rate (IP30) utilized by our third-party engineering firm for our December 31, 2021 reserve report was 388 BOEPD (“Reserve Report IP30”), while the initial 30-day type curve used by the Company’s management for wells in the corridor assumes a 472 BOEPD IP30 rate (“Management IP30”). The Emery 17-3H well 10-day IP rate is higher than the comparable 10-day rate for both the Barnes 8-4H well that was drilled earlier this year and the Glenn 16-2H well. The Glenn 16-2H well was drilled a few years ago in the corridor and was completed with the first generation of our latest completion design. The Barnes 8-4H and the Glenn 16-2H wells ended up with IP30 rates that were about 1.5 and 1.6 times higher, respectively, than the Reserve Report IP30.
Based on the current performance of the well and the expectation that it will perform similarly to our previous core area wells, we anticipate that the well will end up with an IP30 rate that is much higher than the Reserve Report IP30 and above the Management IP30. However, there can be no assurance as to what the Emery 17-3H well’s IP30 rate or ultimate productivity will be.”
Brock 9-3H Well and Glenn 16-3H Well
The Brock 9-3H well and the Glenn 16-3H well have been successfully fracture stimulated, and our team is currently drilling out the fracture stimulation plugs. It is anticipated that flow back on both wells will start later this week.
About Kolibri Global Energy Inc.
Kolibri Global Energy Inc. is a North American energy company focused on finding and exploiting energy projects in oil, gas, and clean and sustainable energy. 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. The Company's shares are traded on the Toronto Stock Exchange under the stock symbol KEI and on the OTCQX under the stock symbol KGEIF.
Cautionary Statements
In this news release and the Company’s other public disclosure: The references to barrels of oil equivalent ("Boes") reflect natural gas, natural gas liquids and oil. Boes may be misleading, particularly if used in isolation. A Boe conversion ratio of 6 Mcf: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. Given that the value ratio based on the current price of crude oil as compared to natural gas is significantly different from the energy equivalency of 6:1, utilizing a conversion on a 6:1 basis may be misleading as an indication of value. Possible reserves are those additional reserves that are less certain to be recovered than probable reserves. There is a 10% probability that the quantities actually recovered will equal or exceed the sum of proved plus probable plus possible reserves. The type curve utilized by the Company’s management is the average of the 7 Caney wells that were drilled prior to December 31st, 2021, are located in the Corridor (well names can be found on the Company’s Corporate presentation), with lateral lengths normalized to a 4,900 ft lateral length, the other assumptions are the same as in the Company’s December 31, 2021 independent reserves evaluation.
Readers should be aware that references to initial production rates and other short-term production rates are preliminary in nature and are not necessarily indicative of long-term performance or of ultimate recovery. Readers are referred to the full description of the results of the Company's December 31, 2021 independent reserves evaluation and other oil and gas information contained in its Form 51-101F1 Statement of Reserves Data and Other Oil and Gas Information for the year ended December 31, 2021, which the Company filed on SEDAR on March 8, 2022.
Caution Regarding Forward-Looking Information
Certain statements contained in this news release constitute "forward-looking information" as such term is used in applicable Canadian securities laws and “forward-looking statements” within the meaning of United States securities laws (collectively, “forward looking information”), including statements regarding the timing of and expected results from planned wells development, the anticipated IP30 rate of the Emery 17-3H well, tubing is scheduled to be installed in the coming weeks, and anticipated timing on beginning the flowback for the Brock 9-3H and Glenn 16-3H wells. 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 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’s 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 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 or labor 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’s operations have unexpected adverse effects on the Company’s operations, that completion techniques require further optimization, that production rates do not match the Company’s 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 www.sedar.com, any of which could result in delays, cessation in planned work or loss of one or more concessions 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.
