Kolibri Global Energy (NASDAQ: KGEI) lifts 2025 reserves and posts $584M NPV

Rhea-AI Filing Summary

Kolibri Global Energy reports a strong reserves update for December 31, 2025, highlighted by a 30% increase in proved developed producing reserves from its 2025 drilling program. The net present value of these developed reserves at a 10% discount rate is about $189 million, even though the 2026 oil price assumption in the reserve report was cut to $58 per barrel from $76 the prior year, while current market prices are above $90 per barrel.

Total proved reserves stand at about 40.8 million BOE, with proved plus probable reserves of roughly 57.6 million BOE, all in the Tishomingo Field in Oklahoma. An independent evaluator, Netherland, Sewell & Associates, values total proved reserves at a before-tax NPV of $440.7 million and proved plus probable reserves at $583.9 million, both at a 10% discount rate under forecast prices and costs.

Kolibri produced about 1.46 million BOE in 2025, averaging 4,013 BOEPD, and reports a three-year compound annual production growth rate of 35%. Management plans further development of the Caney shale, with dozens of additional wells scheduled between 2026 and 2030, and will discuss results on a year-end earnings call on March 19, 2026.

Insights

Energy sector equity analyst

Reserves volumes grew and quality improved, but price-deck cuts weighed on value.

Kolibri Global Energy shows a 30% increase in proved developed producing reserves and total proved reserves of about 40.8 million BOE, all independently evaluated in the Tishomingo Field. This shifts more of the portfolio into lower-risk, producing barrels while maintaining overall reserve size.

However, the before-tax net present value of reserves at a 10% discount is $440.7M for proved and $583.9M for proved plus probable, down versus the prior year because the 2026 oil price assumption fell to $58/bbl from $76/bbl. That sensitivity illustrates how dependent reserve value is on long-term pricing assumptions rather than purely on geology or operations.

The company reports a 35% compound annual production growth rate over three years and 2025 production of 1.46 million BOE with solid operating netbacks. Multiple future wells are scheduled from 2026 through 2030, so subsequent disclosures will show how effectively undeveloped reserves are converted into producing volumes under the existing hedge book and price outlook.

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 6-K

Report of Foreign Private Issuer

Pursuant to Rule 13a-16 or 15d-16

UNDER the Securities Exchange Act of 1934

For the month of March 2026

Commission File No.: 001-41824

Kolibri Global Energy Inc.

(Translation of registrant’s name into English)

925 Broadbeck Drive, Suite 220

Thousand Oaks, CA 91320

(Address of principal executive office)

Indicate by check mark whether the registrant files or will file annual reports under cover of Form 20-F or Form 40-F: Form 20-F ☐ Form 40-F ☒

EXHIBIT INDEX

Exhibit		Description
99.1		Press Release dated March 17, 2026
99.2		Statement of Reserves Data and Other Oil and Gas Information
99.3		Report on Reserves Data by Independent Qualified Reserves Evaluator or Auditor
99.4		Report of Management and Directors on Reserves Data and Other Information

SIGNATURE

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.

	Kolibri Global Energy Inc.
Date: March 17, 2026	By:	/s/ Gary Johnson
	Name:	Gary Johnson
	Title:	Chief Financial Officer

Exhibit 99.1

925 Broadbeck Drive, Suite 220, Thousand Oaks, California 91320 Phone: (805) 484-3613 TSX ticker symbol: KEI NASDAQ ticker symbol: KGEI

For Immediate Release

KOLIBRI GLOBAL ENERGY INC. ANNOUNCES 2025 PROVED DEVELOPED RESERVE INCREASE OF 30% AND YEAREND EARNINGS CALL

Thousand Oaks CALIFORNIA, March 17, 2026 – Kolibri Global Energy Inc. (the “Company” or “KGEI”) (TSX: KEI, NASDAQ: KGEI) is providing the results of its December 31, 2025, independent reserves evaluation. All amounts are in US$ unless otherwise stated.

Wolf Regener, President and CEO, commented: “We are very pleased that our proved developed producing reserves increased by 30 percent due to our successful 2025 drilling program. Proved developed producing reserves valuation (NPV discounted at 10%) increased by 10% to $189 million, despite the much lower oil prices used in this reserve report. The 2026 oil price used in the reserve report is $58 a barrel which is 24% below the previous year’s report of $76 a barrel. This is in stark contrast to current oil prices, which are in excess of $90 per barrel.

“Total proved reserves increased 1% in 2025, even though we drilled almost all of our wells in Proved locations and produced approximately 1.5 million barrels of oil equivalent (BOE) of proved reserves. And, with our percentage of PDP versus Total Proved reserves at 29%, we still have a significant amount of proved undeveloped reserves to be able to convert into future production.

“Over the last three years, we have achieved a fantastic 35% compound annual production growth rate. We look forward to continuing our success with our drilling program this year, which we are planning to begin in June. We are preparing multiple pad locations to quickly give us the ability to increase our drilling activity if oil prices remain elevated through 2026.”

2025 Gross Reserves Summary

● Total Proved Reserves of 40.8 million BOEs

- an increase of 1% from the December 31, 2024, estimate

● Proved plus Probable Reserves of 57.6 million BOEs

- an increase of 7% from the December 31, 2024, estimate

● Proved plus Probable plus Possible Reserves of 71.9 million BOEs

- an increase of 0.5% from the December 31, 2024, estimate

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Net Present Value of Reserves discounted at 10%

● Total Proved Reserves before tax of US$440.7 million

- a decrease of 18% from the December 31, 2024 estimate

● Proved plus Probable Reserves before tax of US$583.9 million

- a decrease of 16% from the December 31, 2024 estimate

● Proved plus Probable plus Possible Reserves before tax of US$726.5 million

- a decrease of 20% from the December 31, 2024 estimate

The evaluation of the Company’s reserves in the Caney formation of the Tishomingo Field in the SCOOP area of Oklahoma was conducted by Netherland, Sewell & Associates, Inc. (“NSAI”) in accordance with National Instrument 51-101 – Standards of Disclosure for Oil and Gas Activities.

The above total Proved reserves are attributed to the 45 Caney wells, four Woodford wells (4.9% working interest for the Company) and one Sycamore well (0.7% working interest for the Company), and the drilling of 34.85 net additional wells over the next four years. The Probable reserves are attributed to the drilling of 10.92 net additional wells over the next five years. The wells in NSAI’s 2025 report are planned at 107 to 213 acre spacing (6 wells per section) on approximately 17,696 net acres.

		Summary of Oil & Gas Reserves
		Tight Oil								Shale Gas								Natural Gas Liquids								MBOEs
Reserve Category		KGEI Gross (Mbbl)				Net (Mbbl)				KGEI Gross (MMcf)				Net (MMcf)				KGEI (Mbbl)				Net (Mbbl)				KGEI (Mbbl)				Net (Mbbl)
Proved
Developed Producing			7,937				6,215				9,976				7,796				2,134				1,668				11,732				9,181
Undeveloped			18,232				14,443				28,409				22,480				6,071				4,804				29,038				22,994
Total Proved			26,169				20,658				38,385				30,277				8,205				6,472				40,770				32,175
Probable			10,342				8,226				17,021				13,547				3,638				2,895				16,816				13,379
Total Proved Plus Probable			36,511				28,884				55,406				43,823				11,843				9,368				57,586				45,554
Possible			10,336				8,268				10,324				8,224				2,207				1,758				14,262				11,396
Total Proved Plus Probable Plus Possible			46,846				37,152				65,730				52,048				14,050				11,126				71,848				56,950

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Net Present Value of Future Net Revenue

As of December 31, 2025

Forecast Prices & Costs

		Net Present Value of Future Net Revenue ($ millions)
		Before Income Tax																				After Income Tax
Reserve Category		0%				5%				10%				15%				20%				0%				5%				10%				15%				20%
United States
Proved
Developed Producing			334.6				241.0				188.9				156.6				134.9				334.5				241.0				188.9				156.6				134.9
Undeveloped			662.1				388.6				251.7				172.9				122.7				431.2				268.5				173.6				115.3				77.5
Total Proved			996.7				629.5				440.7				329.5				257.5				765.7				509.5				362.5				271.9				212.4
Probable			490.6				242.9				143.2				93.8				65.7				363.3				193.7				115.0				74.8				52.3
Total Proved Plus Probable			1,487.3				872.4				583.9				423.3				323.2				1,129.0				703.2				477.5				346.7				264.7
Possible			575.2				252.4				142.6				92.7				65.3				426.0				200.0				109.0				67.7				46.4
Total Proved Plus Probable plus Possible			2,062.5				1,124.8				726.5				516.0				388.6				1,555.0				903.2				586.5				414.4				311.1

Note: All dollar values are expressed in U.S. dollars and may not add due to rounding.

The Company’s reserves are derived from non-conventional oil and gas activities. The Company’s reserves are contained in a shale oil reservoir from which light/medium oil is produced and gas and natural gas liquids are produced as by-products. In previous statements, the light/medium oil was referred to as “tight oil”.

These after-income tax net present values reflect the tax burden on the Company’s Tishomingo Field interests on a standalone basis, do not consider the business-entity-level tax situation or tax planning, and do not provide an estimate of the value at the level of the business entity, which may be significantly different. The financial statements and the management’s discussion and analysis (MD&A) of the Company should be consulted for information at the level of the business entity.

Readers are referred to the Company’s Form 51-101F1 Statement of Reserves Data and Other Oil & Gas Information for the year ended December 31, 2025, which can be accessed electronically from the SEDAR+ website at www.sedarplus.ca, for additional information.

Year End Earnings Release and Earnings Call

The Company expects to release financial and operating results for 2025 before the market opens on March 19, 2026.

In connection with the earnings release, management will host a conference call for investors and analysts on March 19, 2026, at 9:00 a.m. Pacific time to discuss the Company’s results and to host a Q&A session. Interested parties are invited to participate by calling:

Dial-In: 1-833-890-5570

International Dial-In: 1-412-504-9708

When calling, please request to be joined into the Kolibri Global Energy Inc. call.

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“BOEs” refers to barrels of oil equivalent. BOEs/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. 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 provided plus probable plus possible reserves. The present value of estimated future net revenues referred to herein does not represent fair market value and should not be construed as the current market value of estimated crude oil and natural gas reserves attributable to the Company’s properties. 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.

This news release includes references to sales volumes of “oil”, “natural gas”, and “barrels of oil equivalent” or “BOEs”. “Oil” 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 plant where it is treated and sold as natural gas and NGLs.

About Kolibri Global Energy Inc.

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.

For further information, contact:

Wolf E. Regener           +1 (805) 484-3613

Email: wregener@kolibrienergy.com

Website: www.kolibrienergy.com

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, including statements regarding estimates of reserves and future net revenue and cash flow, expectations regarding additional reserves and statements regarding Caney wells development, including plans, anticipated results, and timing and the Company’s working interest, and expectations regarding the Company’s 2026 drilling program. 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. Estimated reserves and future net revenue have been independently evaluated by NSAI with an effective date of December 31, 2025. This evaluation is based on a limited number of wells with limited production history and includes a number of assumptions relating to factors such as availability of capital to fund required infrastructure, commodity prices, production performance of the wells drilled, successful drilling of infill wells, the assumed effects of regulation by government agencies and future capital and operating costs. All of these estimates will vary from actual results. Estimates of the recoverable oil and natural gas reserves attributable to any particular group of properties, classifications of such reserves based on risk of recovery and estimates of future net revenues expected therefrom, will vary. The Company’s actual production, revenues, taxes, development and operating expenditures with respect to its reserves will vary from such estimates, and such variances could be material. Estimates of after-tax net present value are dependent on a number of factors including utilization of tax-loss carry forwards. In addition to the foregoing, other significant factors or uncertainties that may affect either the Company’s reserves or the future net revenue associated with such reserves include material changes to existing taxation or royalty rates and/or regulations, and changes to environmental laws and regulations. Forward-looking information regarding Caney wells development and expectations regarding additional reserves are based on plans and estimates of management and interpretations of exploration information by the Company’s exploration team at the date the information is provided and is subject to several factors and assumptions of management, including that required regulatory approvals and capital will be available when required, 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 demand for oil and gas will be sustained, that the price of oil will be sustained or increase, that no unforeseen delays, unexpected geological or other effects, equipment failures, permitting delays or labor or contract disputes or shortages are encountered, that the development plans of the Company and its co-venturers will not change, and 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, including that anticipated results and estimated costs will not be consistent with managements’ expectations, the risk of commodity price and foreign exchange rate fluctuations, the Company or its subsidiaries not being 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 capital is not available when required, that unexpected geological results are encountered and that equipment failures, permitting delays or labor or contract disputes or shortages are encountered.

Information on other important economic factors or significant uncertainties that may affect components of the reserves data and the other forward looking statements in this release are contained in the Company’s Form 51-101F1 Statement of Reserves Data and Other Oil & Gas Information for the year ended December 31, 2025, the Company’s Management Discussion and Analysis and the Company’s Annual Information Form under “Risk Factors”, which are available under the Company’s profile at www.sedarplus.ca. The Company undertakes no obligation to update forward-looking statements, other than as required by applicable law.

Exhibit 99.2

FORM 51-101F1 –

STATEMENT OF RESERVES DATA

AND OTHER OIL AND GAS INFORMATION

For the Year Ended December 31, 2025

March 17, 2026

TABLE OF CONTENTS

PART 1: INTRODUCTION		4
PART 2: DISCLOSURE OF RESERVES DATA		5
	2.1 Reserves Data (Forecast Prices and Costs)	5
PART 3: PRICING ASSUMPTIONS		7
	3.1 Forecast Prices Used in Estimates	7
PART 4: RECONCILIATIONS OF CHANGES IN RESERVES AND FUTURE NET REVENUE		8
	4.1 Reserves Reconciliation	8
PART 5: ADDITIONAL INFORMATION RELATING TO RESERVES DATA		9
	5.1 Undeveloped Reserves	9
	5.2 Significant Factors or Uncertainties	9
	5.3 Future Development Costs	10
PART 6: OTHER OIL AND GAS INFORMATION		11
	6.1 Oil and Gas Properties and Wells	11
	6.2 Properties with No Attributed Reserves	12
	6.3 Forward Contracts	12
	6.4 Tax Horizon	13
	6.5 Costs Incurred	13
	6.6 Exploration and Development Activities	13
	6.7 Production Estimates	14
	6.8 Production History	14
PART 7: NOTES		15

GLOSSARY OF TERMS

“AIF” refers to the Company’s Annual Information Form filed on SEDAR+

“AIT” stands for ‘After Income Taxes’;

“BIT” stands for ‘Before Income Taxes’;

“Company” or “KGEI” means Kolibri Global Energy Inc.;

“NSAI” means Netherland, Sewell & Associates, Inc., independent petroleum engineering consultants of Houston, Texas, U.S.;

“NI 51-101” refers to National Instrument 51-101; and

“Woodford Sale” means the sale by Kolibri Energy US Inc. of its Tishomingo field assets, excluding the Caney and Upper Sycamore formations, the completion of which was announced by the Company on April 21, 2013.

Abbreviations

Bbl	Barrel
Bbls	Barrels
Bcfe	Billion cubic feet of gas equivalent
Boe	Barrels of oil equivalent (converted at 6 Mcf to 1 Boe)
Bopd	Barrels of oil per day
Mbbls	Thousand barrels
MMboe	Millions of barrels of oil equivalent
Mcf	Thousand cubic feet
MMcf	Million cubic feet
Mcf/d	Thousand cubic feet per day
Bcf	Billion cubic feet

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PART 1: INTRODUCTION

The effective date of the information being provided in this statement is December 31, 2025. The preparation date of the information being provided in this statement is March 17, 2026. For a glossary of terminology and definitions relating to the information included within this statement (including the aforementioned dates), readers are referred to NI 51-101.

Reserves and Future Net Revenue

The following is a summary of the oil and natural gas reserves and the net present values of future net revenue of Kolibri Global Energy Inc.’s wholly owned subsidiary Kolibri Energy US Inc. as evaluated by NSAI. The Company’s only property with assigned reserves and gathering revenue is the Tishomingo field in Oklahoma, U.S. NSAI is an independent qualified reserves evaluator appointed by the Company pursuant to NI 51-101. Readers should note that totals in the following tables may not add due to rounding.

The estimated future net revenue figures contained in the following tables do not necessarily represent the fair market value of the Company’s reserves. There is no assurance that the forecast prices and cost assumptions used by NSAI in its report to the Company will be attained and variances could be material. NSAI’s report to the Company contained additional assumptions relating to costs and other matters. The recovery and reserves estimates attributed to the Company’s properties described herein are estimates only. The actual reserves attributed to the Company’s properties may be greater or less than those calculated.

All dollar values are expressed in U.S. dollars, unless otherwise indicated.

Cautionary Statements

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.

BOEs may be misleading, particularly if used in isolation. A boe conversion ratio of six mcf to one barrel is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead.

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PART 2: DISCLOSURE OF RESERVES DATA

2.1 Reserves Data (Forecast Prices and Costs)

		United States
		Tight Oil								Shale Gas								Natural Gas Liquids
Reserve Category		KGEI Gross (Mbbl)				Net (Mbbl)				KGEI Gross (MMcf)				Net (MMcf)				KGEI Gross (Mbbl)				Net (Mbbl)
Proved
Developed Producing			7,937				6,215				9,976				7,796				2,134				1,668
Undeveloped			18,232				14,443				28,409				22,480				6,071				4,804
Total Proved			26,169				20,658				38,385				30,277				8,205				6,472
Probable			10,342				8,226				17,021				13,547				3,638				2,895
Total Proved Plus Probable			36,511				28,884				55,406				43,823				11,843				9,368
Possible			10,336				8,268				10,324				8,224				2,207				1,758
Total Proved Plus Probable Plus Possible			46,846				37,152				65,730				52,048				14,050				11,126

Notes: May not add due to rounding. The Company’s reserves are derived from non-conventional oil and gas activities. The Company’s reserves are contained in a shale oil reservoir from which gas and natural gas liquids are produced as by-products.

Summary of Oil & Gas Reserves

As of December 31, 2025

Forecast Prices & Costs

		Reserves Total
Reserve Category		KGEI Gross (MBOE)				Net (MBOE)
Proved
Developed Producing			11,734				9,182
Undeveloped			29,038				22,994
Total Proved			40,772				32,177
Probable			16,816				13,379
Total Proved Plus Probable			57,588				45,556
Possible			14,263				11,396
Total Proved Plus Probable Plus Possible			71,851				56,952

Note: May not add due to rounding. Boe basis: 6 Mcf to 1 Bbl

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Net Present Value of Future Net Revenue

As of December 31, 2025

Forecast Prices & Costs

		Net Present Value of Future Net Revenue ($ millions)
		Before Income Tax																				After Income Tax
Reserve Category		0%				5%				10%				15%				20%				0%				5%				10%				15%				20%
United States
Proved
Developed Producing			334.6				241.0				188.9				156.6				134.9				334.5				241.0				188.9				156.6				134.9
Undeveloped			662.1				388.6				251.7				172.9				122.7				431.2				268.5				173.6				115.3				77.5
Total Proved			996.7				629.5				440.7				329.5				257.5				765.7				509.5				362.5				271.9				212.4
Probable			490.6				242.9				143.2				93.8				65.7				363.3				193.7				115.0				74.8				52.3
Total Proved Plus Probable			1,487.3				872.4				583.9				423.3				323.2				1,129.0				703.2				477.5				346.7				264.7
Possible			575.2				252.4				142.6				92.7				65.3				426.0				200.0				109.0				67.7				46.4
Total Proved Plus Probable plus Possible			2,062.5				1,124.8				726.5				516.0				388.6				1,555.0				903.2				586.5				414.4				311.1

Notes: May not add due to rounding. The after income tax net present values presented in the preceding table take into account available non-operating tax losses of $106 million and reflect the tax burden on the Company’s Tishomingo Field interests on a standalone basis, do not consider the business-entity-level tax situation or tax planning and do not provide an estimate of the value at the level of the business entity, which may be significantly different. The financial statements and the management’s discussion and analysis (MD&A) of the Company should be consulted for information at the level of the business entity.

Total Future Net Revenue (Undiscounted - by Reserve Category)

As of December 31, 2025

Forecast Prices & Costs ($ millions)

Reserve Category		Company Gross Revenue				Royalties				Operating Expenses				Severance Taxes				Develop. Costs				Abandonment & Reclamation Costs				Future Net Revenue BIT				Income Taxes				Future Net Revenue AIT
Total Proved			2,324.5				489.5				449.3				119.4				258.0				11.5				996.7				231.0				765.7
Total Proved Plus Probable			3,393.7				708.4				656.0				175.4				351.7				15.0				1,487.3				358.3				1,129.0
Total Proved Plus Probable Plus Possible			4,481.8				927.2				835.8				233.6				404.9				17.8				2,062.5				507.5				1,555.0

Total Future Net Revenue (NPV discounted 10%, BIT by Reserve Category)

As of December 31, 2025

Forecast Prices & Costs

Reserve Category		$ millions				Unit Value ($/boe)
Total Proved
Tight Oil (1)			440.7				13.7
Total Proved Plus Probable
Tight Oil (1)			583.9				12.82
Total Proved Plus Probable Plus Possible
Tight Oil (1)			726.5				12.76

(1) Includes solution gas and other by-products (NGL’s)

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PART 3: PRICING ASSUMPTIONS

3.1 Forecast Prices Used in Estimates

Forecast benchmark reference product price and inflation rate assumptions are summarized below. These forecast assumptions with adjustments were provided in the NSAI report.

Summary of Pricing & Inflation Rate Assumptions

As of December 31, 2025

Forecast Prices & Costs

						United States
		WTI*				Henry Hub*				NGL				Inflation Rate
Year		US$/bbl				US$/MMbtu				US$/bbl				%
2026			58.00				3.50				15.66
2027			63.00				3.50				17.01
2028			68.00				3.50				18.36
2029			69.36				3.57				18.73
2030			70.75				3.64				19.10
2031			72.16				3.71				19.48
2032			73.61				3.79				19.87
2033			75.08				3.86				20.27
2034			76.58				3.94				20.68
2035			78.11				4.02				21.09
															2.0

Note: Sproule Oil & Natural Gas Forecast from NSAI Report to the Company including adjustments for NGL differentials; prices escalated @ 2% after 2035.

2025 weighted average prices were: $63.32 for oil, $3.05 for natural gas and $20.29 for NGLs.

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PART 4: RECONCILIATIONS OF CHANGES IN RESERVES AND FUTURE NET REVENUE

4.1 Reserves Reconciliation

A reconciliation of changes to the Company’s gross (before deduction of royalties) proved, probable and proved plus probable reserves is provided below. This reconciliation reflects changes to the Company’s reserves estimated using forecast prices and costs.

		United States
		Tight Oil												Shale Gas												Natural Gas Liquids
		Proved				Probable				Proved + Probable				Proved				Probable				Proved + Probable				Proved				Probable				Proved + Probable
		(Mbbl)				(Mbbl)				(Mbbl)				(MMcf)				(MMcf)				(MMcf)				(Mbbl)				(Mbbl)				(Mbbl)
31-Dec-24			26,532.0				9,159.7				35,691.7				33,206.5				10,409.6				43,616.1				8,128.1				2,547.0				10,675.1
Extensions(2)			1,739.7				(1,927.8	)			(188.1	)			1,753.7				(1,477.0	)			276.7				374.8				(368.1	)			6.6
Improved Recovery			-				-				-				-				-				-				-				-				-
Technical Revisions(3)			(1,711.4	)			431.1				(1,280.3	)			3,097.8				1,019.2				4,117.1				(390.0	)			(51.8	)			(441.7	)
Discoveries(4)			1.3				0.6				1.9				2.3				0.9				3.3				0.5				0.2				0.7
Acquisitions(5)			605.1				2,679.4				3,284.6				1,621.7				7,069.1				8,690.7				346.6				1,510.7				1,857.3
Dispositions(5)			(3.0	)			(1.3	)			(4.2	)			(2.5	)			(1.2	)			(3.7	)			(0.5	)			(0.3	)			(0.8	)
Economic Factors			-				-				-				-				-				-				-				-				-
Production			(994.8	)			-				(994.8	)			(1,294.4	)			-				(1,294.4	)			(254.0	)			-				(254.0	)
31-Dec-25(1)			26,168.9				10,341.8				36,510.6				38,385.2				17,020.7				55,405.8				8,205.5				3,637.8				11,843.3

Note:

	(1)	Totals may not add due to rounding. Boe basis: 6 Mcf to 1 Bbl.
	(2)	Consists of one new producing well that was previously classified as contingent resource, and six undeveloped locations that were moved from probable to proved as a result of drilling new producing wells in proximity to these locations.
	(3)	Consists of performance based adjustments on producing wells and updates to reserves on undeveloped locations.
	(4)	Consists of one new non-operated producing well in a reservoir with no reserves previously booked.
	(5)	Consists of positive and negative changes in company interest in certain development wells.

-8-

PART 5: ADDITIONAL INFORMATION RELATING TO RESERVES DATA

5.1 Undeveloped Reserves

The Company’s undeveloped reserves exist in the Caney shale of its interests in the Tishomingo Field in Oklahoma, U.S. Most of these reserves are designated within the undeveloped category because significant capital expenditures will be required in order to render these reserves capable of production.

The following tables disclose the proved undeveloped and probable undeveloped reserves from the Company’s current net interest in the Tishomingo Field that were first attributed in each of the most recent three financial years:

		Oil (Mbbl)								Natural Gas MMcf								NGL
Proved Undeveloped Reserves		First Attributed				Booked at Year End				First Attributed				Booked at Year End				First Attributed				Booked at Year End
12/31/2023			0.0				14,090.5				0.0				13,149.8				55.9				3,029.3
12/31/2024			4,919.2				16,119.2				6,823.1				20,771.3				1,669.4				5,082.0
12/31/2025			0.0				14,443.5				0.0				22,480.0				0.0				4,804.2

		Oil (Mbbl)								Natural Gas MMcf								NGL
Probable Undeveloped Reserves		First Attributed				Booked at Year End				First Attributed				Booked at Year End				First Attributed				Booked at Year End
12/31/2023			1,209.7				11,952.6				0.0				11,440.1				0.0				2,635.5
12/31/2024			935.3				6,558.2				651.0				7,403.0				159.3				1,811.3
12/31/2025			0.0				7,298.2				0.0				12,460.5				0.0				2,662.9

Plans for future development of these undeveloped reserves (based on Forecast Prices and Costs) are summarized below:

United States of America Properties

Tishomingo Field, Oklahoma

NSAI assigns 29,038 Mboe (Company Gross Working Interest share) Proved Undeveloped and 12,038 Mboe (Company Gross Working Interest share) Probable Undeveloped reserves to the Tishomingo Field. The Proved Undeveloped reserves are forecast to be recoverable from the drilling of 11 wells in 2026 and 17, 19 and 1 well in 2027, 2028 and 2029 respectively (7.84, 13.85, 12.20 and 0.97 net KGEI wells). The Probable Undeveloped reserves are forecast to be recoverable from the drilling of 10 wells in 2029, and 14 wells in 2030 respectively (6.05 and 4.87 net KGEI wells).

The production forecast is based on producing the existing wells and drilling the additional wells as listed above and applying the historical production behavior to the undeveloped well locations.

5.2 Significant Factors or Uncertainties

Estimates of economically recoverable oil and natural gas reserves (including natural gas liquids) and the future net cash flows therefrom are based upon a number of variable factors and assumptions, such as availability of capital to fund required infrastructure, commodity prices, production performance of the wells drilled, successful drilling of infill wells, the assumed effects of regulation by government agencies and future capital and operating costs. All of these estimates will vary from actual results. Estimates of the recoverable oil and natural gas reserves attributable to any particular group of properties, classifications of such reserves based on risk of recovery and estimates of future net revenues expected therefrom, will vary. The Company’s actual production, revenues, taxes, development and operating expenditures with respect to its reserves will vary from such estimates, and such variances could be material. Estimates of after-tax net present value are dependent on a number of factors including utilization of tax-loss carry forwards. In addition to the foregoing, other significant factors or uncertainties that may affect either the Company’s reserves or the future net revenue associated with such reserves include material changes to existing taxation or royalty rates and/or regulations, and changes to environmental laws and regulations.

-9-

Information on other important economic factors or significant uncertainties that may affect components of the reserves data and other oil and gas information contained in this Form 51-101F1 are contained in the Company’s Management Discussion and Analysis filed under the Company’s profile at www.sedarplus.ca and in the AIF under “Risk Factors”.

5.3 Future Development Costs

A summary of the estimated development costs deducted in the estimation of future net revenue attributable to various reserves categories and prepared under various price and cost assumptions are summarized in the following table. The Company expects to fund its estimated future development costs through some combination of internally generated cash flow and debt or equity financing. There can be no guarantee that funds will be available when required to proceed with the development on the schedule contemplated herein or that the Board of Directors of the Company will allocate funding to develop all of the reserves requiring development. Failure to develop such reserves could negatively impact future net revenue.

Summary of Estimated Development Costs Attributed to Reserves

Forecast Prices & Costs

		Estimated Development Costs ($ millions)
		Total Proved				Total Proved + Probable
United States
2026			76.1				76.1
2027			111.8				111.8
2028			66.7				71.8
2029			3.4				60.2
2030			0				31.7
Total			258.0				351.7

-10-

PART 6: OTHER OIL AND GAS INFORMATION

6.1 Oil and Gas Properties and Wells

The following discussion outlines the Company’s important properties, plants, facilities and installations:

United States

Tishomingo Field, Ardmore Basin, Oklahoma

In Oklahoma, the Company currently holds approximately 17,700 net acres of Caney shale acreage in the Tishomingo Field near Ardmore, OK. The Company originally drilled wells to the slightly deeper Woodford shale in this field. In April 2013, the Company sold some of its rights in the Tishomingo Field, keeping the rights to the Caney and the upper Sycamore formations, where it had previously drilled and tested two wells. Beginning in 2013, the Company began focusing primarily on developing the oily Caney shale. A subsequent transaction in 2015 resulted in the Company obtaining a 4.9% working interest in one section and participating in four Woodford shale horizontal wells which were completed in 2016. Over the years, the Company increased its net acreage position from about 12,500 to about 17,700 net acres currently. The Company plans to continue development drilling in this field with the objective of increasing production and proved reserves. The Company’s oil is trucked from the field and its wells are connected to a 3^rd party gathering system, whose operator markets and sells the gas and NGL’s.

In 2025, the Company drilled 7 wells (6 were longer lateral wells) and completed 9 wells (2 were drilled in 2023). As of December 31, 2025, the Company has 45 completed Caney wells, a very small interest in one completed Sycamore well, and small interests in 4 Woodford wells, all of which are on production. Production averaged 4,013 BOEPD in 2025, with the production of 1.46 million oil equivalent barrels in 2025. KGEI’s 2025 year-end proved reserves were 40.8 million BOE, and its proved and probable reserves were 57.6 million BOE.

Oil & Gas Properties Associated with Reserves

As of December 31, 2025

				Acreage																								Plants, Facilities &
				Developed								Undeveloped								Total								Installation
Properties		Location		Gross				Net				Gross				Net				Gross				Net
United States
Tishomingo		Oklahoma, U.S.			14,756				10,817				14,740				6,819				29,496				17,696
Total					14,756				10,817				14,740				6,819				26,496				17,696

Oil & Gas Properties Associated with Reserves

As of December 31, 2025

		United States
		Tight Oil								Shale Gas								Natural Gas Liquids								Suspended				Service				Total
		Gross				Net				Gross				Net				Gross				Net				(1)				(2)				Gross				Net
Oklahoma Producing			46				41.9				4.0				0.2																				50			42.1
Oklahoma Non-Producing
Total			46				41.9				4.0				0.2																				50			42.1

(1) Suspended wells may be capable of production but which, for a variety of reasons, including, but not limited to lack of markets or development are not placed on production at the present time. (2) Service wells are used for the disposal or injection of water or other in-field service operations related to oil and gas product.

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6.2 Properties with No Attributed Reserves

The Company’s unproved properties, including those for which the Company expects its rights to explore, develop and exploit to expire within one year, are outlined in the following table.

Properties with no Attributed Reserves

As of December 31, 2025

				Undeveloped Acreage (Acres)								Company Interest				Work Commitments (existence, nature, timing & cost)
Properties		Location		Gross				Net				(%)
United States
Tishomingo		Carter & Johnson County, OK			2,560				59				2			99% is held by production with working interest over numerous sections
Baum		Carter & Johnson County, OK			5,760				10				0.2
McIntosh County		McIntosh County, OK			3,840				43				1			Held by production with small interests spread over numerous sections.
Total					12,160				112

6.3 Forward Contracts

The Company is not bound by any agreements which may impact the realization of future full market prices for its oil and gas production as described in this report, other than the financial commodity contracts listed below as of December 31, 2025.

Commodity		Period				Total Volume Hedged (BBLS)				Price ($/BBL)
Oil – WTI Costless Collars			January 1, 2026 to March 31, 2026				48,000			$	58.50 - $77.25
Oil – WTI Deferred Put			January 1, 2026 to March 31, 2026				20,589			$	50.00
Oil – WTI Costless Collars			April 1, 2026 to June 30, 2026				48,300			$	57.00 - $75.25
Oil – WTI Deferred Put			April 1, 2026 to June 30, 2026				9,900			$	52.70
Oil – WTI Deferred Put			April 1, 2026 to June 30, 2026				3,900			$	49.50
Oil – WTI Costless Collars			July 1, 2026 to September 30, 2026				48,300			$	50.25 - $66.75
Oil – WTI Deferred Put			July 1, 2026 to September 30, 2026				13,800			$	49.50
Oil – WTI Costless Collars			October 1, 2026 to December 31, 2026				24,000			$	52.25 - $69.00
Oil – WTI Costless Collars			October 1, 2026 to December 31, 2026				5,100			$	52.60 - $70.00
Oil – WTI Deferred Put			October 1, 2026 to December 31, 2026				14,400			$	49.75
Oil – WTI Deferred Put			January 1, 2027 to March 31, 2027				36,000			$	49.75

The Company has no transportation obligations or commitments for future deliveries which exceed its expected related future production from proved reserves, as estimated using forecast prices and costs.

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6.4 Tax Horizon

The Company does not expect to be required to pay federal and Oklahoma state income taxes in the immediate foreseeable future. Since California suspended the utilization of net operating losses until 2026, the Company is expected to be required to pay California state taxes during 2025 and 2026.

6.5 Costs Incurred

For the year ended December 31, 2025, the Company incurred costs related to its acquisition, exploration and development activities as outlined in the following table.

		Cost Incurred ($ millions)
		United States
Property Acquisition Costs
Proved Properties		$	0.2
Unproved Properties/Wells			Nil
Exploration Costs		$	0.1
Development Costs		$	62.3

6.6 Exploration and Development Activities

The Company’s drilling and completion activity and results for the year ended December 31, 2025, are summarized in the following table. It should be noted that the data outlined in this table reflects those wells that the Company participated in and where the rig was released during the period.

		Exploratory Wells								Development Wells
		Gross				Net				Gross				Net
United States
Oil Wells			1.0				0.01				9.0				8.4
Gas Wells			0.0				0.0				0.0				0.0
Service Wells			0.0				0.0				0.0				0.0
Stratigraphic Test Wells			0.0				0.0				0.0				0.0
Dry Holes			0.0				0.0				0.0				0.0
Total Wells			1.0				0.01				9.0				8.4

The Company’s exploration and development activities are summarized as follows:

United States

During fiscal year 2025 KGEI drilled seven and completed nine Caney wells in its Tishomingo Field. The Company also participated with a very small interest in one Sycamore exploration well. The Company plans additional development drilling in the Tishomingo Field, OK, with the objective of increasing production and reserves.

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6.7 Production Estimates

Estimated production volumes (before Royalties) derived from the first year (2026) of the cash flow forecasts prepared in conjunction with the Company’s reserves data included in the NSAI Report are provided in the following table.

Summary of Production Estimates

Proved + Probable Reserves Case

For Year 2026

United States

Tight Oil

Shale Gas

Natural Gas Liquids

Company Total

Reserve Category

(Mbbl)

(MMcf)

(Mbbl)

(Mboe)

United States

Tishomingo, OK

1,714.7

2,024.0

432.8

2,484.8

Total

1,714.7

2,024.0

432.8

2,484.8

(1) Significant fields represent greater than 20% of Company total (by country) of production in the first year of forecast

6.8 Production History

The Company’s historical production and netback data for period ended December 31, 2025 is presented below.

Summary of 2025 Company Share of Production & Netbacks

		United States
		Q1				Q2				Q3				Q4				Total Year
Company share of daily production before deduction of royalties
Shale Gas (Mcf/d)			3,803				2,880				3,861				3639				3,546
Tight Oil (bopd)			2,844				2,115				2,809				3,131				2,726
NGLs (bopd)			599				625				801				755				696
Average ($/bbl or $/mcf)
Price received ($/boe)			57.28				47.06				48.38				44.39				49.22
Royalties paid			(12.66	)			(10.25	)			(10.17	)			(8.73	)			(10.40	)
Production costs			(7.07	)			(7.15	)			(7.37	)			(7.67	)			(7.33	)
Netback from operations			37.55				29.66				30.84				27.99				31.49
Price adjustment from commodity contracts			-				0.13				0.05				0.32				0.13
Netback after adjustments			37.55				29.79				30.89				28.31				31.62
Total Production (mboe before deductions of royalties)			366.9				293.0				391.3				413.3				1,464.5

Boe basis: 6 Mcf to 1 Bbl

-14-

PART 7: NOTES

The following definitions and guidelines are contained in Section 5.4 of Volume 1 of the Canadian Oil and Gas Evaluation Handbook (Second Edition, September 1, 2007) prepared jointly by The Society of Petroleum Evaluation Engineers (Calgary Chapter) and the Canadian Institute of Mining, Metallurgy & Petroleum (Petroleum Society) (the “COGE Handbook”) and have been prepared by the Standing Committee on Reserves Definitions of the CIM (Petroleum Society). Readers should consult the COGE Handbook for additional explanation and guidance. Certain other terms used in this Listing Application have the meanings assigned to them in NI 51-101 and accompanying Companion Policy 51-101 CP, adopted by the Canadian securities regulatory authorities.

Gross

(a) In relation to the Company’s interest in production or reserves, its “company gross reserves”, which are the Company’s working interest (operating or non-operating) share before deduction of royalties and without including any royalty interest of the Company.

(b) In relation to wells, the total number of wells in which the Company has an interest.

(c) In relation to properties, the total area of properties in which the Company has an interest.

Net

(a) In relation to the Company’s interest in production or reserves, the Company’s working interest (operating and non-operating) share after deduction of royalty obligations, plus the Company’s royalty interests in production or reserves.

(b) In relation to the Company’s interest in a property, the total area in which the Company has an interest multiplied by the working interest owned by the Company.

The following definitions apply to both estimates of individual reserves entities and the aggregate of reserves for multiple entities:

Reserve Categories

Reserves are estimated remaining quantities of oil and natural gas and related substances anticipated to be recoverable from known accumulations from a given date forward, based on:

▪ Analysis of drilling, geological, geophysical and engineering data;

▪ The use of established technology; and

▪ Specified economic conditions

Reserves are classified according to the degree of certainty associated with the estimates:

(a) 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.

(b) 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.

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Development and Production Status

Each of the reserve categories (proved and probable) may be divided into developed and undeveloped categories:

(a) Developed reserves are those reserves that are expected to be recovered from existing wells and installed facilities or, if facilities have not been installed, that would involve a low expenditure (for example, when compared to the cost of drilling a well) to put the reserves on production. The developed category may be subdivided into producing and non-producing.

(i) 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.

(ii) Developed non-producing reserves are those reserves that either have not been on production, or have previously been on production, but are shut-in, and the date of resumption of production is unknown.

(b) Undeveloped reserves are those reserves expected to be recovered from known accumulations where a significant expenditure (for example, when compared to the cost of drilling a well) is required to render them capable of production. They must fully meet the requirements of the reserves classification (proved, probable) to which they are assigned.

In multi-well pools it may be appropriate to allocate total pool reserves between the developed and undeveloped categories or to subdivide the developed reserves for the pool between developed producing and developed non-producing. This allocation should be based on the estimator’s assessment as to the reserves that will be recovered from specific wells, facilities and completion intervals in the pool and their respective development and production status.

Levels of Certainty for Reported Reserves

The qualitative certainty levels referred to in the definitions above are applicable to individual reserve entities (which refers to the lowest level at which reserves calculations are performed) and to reported reserves (which refers to the highest level sum of individual entity estimates for which reserves are presented). Reported reserves should target the following levels of certainty under a specific set of economic conditions:

▪ At least a 90 percent probability that the quantities actually recovered will equal or exceed the estimated proved reserves; and

▪ At least a 50 percent probability that the quantities actually recovered will equal or exceed the sum of the estimated proved plus probable reserves.

A quantitative measure of the certainty levels pertaining to estimates prepared for the various reserves categories is desirable to provide a clearer understanding of the associated risks and uncertainties. However, the majority of reserves estimates will be prepared using deterministic methods that do not provide a mathematically derived quantitative measure of probability. In principle, there should be no difference between estimates prepared using probabilistic or deterministic methods.

Forecast prices and costs

Future prices and costs that are:

(a) Generally accepted as being a reasonable outlook of the future; and

(b) If, and only to the extent that, there are fixed or presently determinable future prices or costs to which the Company is legally bound by a contractual or other obligation to supply a physical product, including those for an extension period of a contract that is likely to be extended, those prices or costs rather than the prices and costs referred to in paragraph (a).

The forecast summary pricing table identifies benchmark reference pricing that apply to the Company.

Product Type Disclosure

This statement includes references to sales volumes of “oil”, “natural gas”, and “barrels of oil equivalent” or “BOEs”. “Oil” 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 statement in BOEs, consists of mainly oil and associated wet gas. The wet gas is delivered via gathering system and then pipelines to processing plant where it is treated and sold as natural gas and NGLs.

-16-

Exhibit 99.3

FORM 51-101F2

REPORT ON RESERVES DATA

BY

INDEPENDENT QUALIFIED RESERVES

EVALUATOR OR AUDITOR

To the board of directors of Kolibri Global Energy Inc. (the “Company”):

1.	We have evaluated the Company’s reserves data as at December 31, 2025. The reserves data are estimates of proved reserves and probable reserves and related future net revenue as at December 31, 2025, estimated using forecast prices and costs.
2.	The reserves data are the responsibility of the Company’s management. Our responsibility is to express an opinion on the reserves data based on our evaluation.
3.	We carried out our evaluation in accordance with standards set out in the Canadian Oil and Gas Evaluation Handbook as amended from time to time (the “COGE Handbook”) maintained by the Society of Petroleum Evaluation Engineers (Calgary Chapter).
4.	Those standards require that we plan and perform an evaluation to obtain reasonable assurance as to whether the reserves data are free of material misstatement. An evaluation also includes assessing whether the reserves data are in accordance with principles and definitions presented in the COGE Handbook.
5.	The following table shows the net present value of future net revenue (before deduction of income taxes) attributed to proved plus probable reserves, estimated using forecast prices and costs and calculated using a discount rate of 10 percent, included in the reserves data of the Company evaluated for the year ended December 31, 2025, and identifies the respective portions thereof that we have evaluated and reported on to the Company’s management:

Independent Qualified Reserves Evaluator

Effective Date of

Location of Reserves (Country or Foreign

Net Present Value of Future Net Revenue (before income taxes, 10% discount rate) [(US$)]

or Auditor

Evaluation Report

Geographic Area)

Audited

Evaluated

Reviewed

Total

Netherland, Sewell & Associates, Inc.

December 31, 2025

United States

nil

583,859,100

nil

583,859,100

6.	In our opinion, the reserves data respectively evaluated by us have, in all material respects, been determined and are in accordance with the COGE Handbook, consistently applied. We express no opinion on the reserves data that we reviewed but did not audit or evaluate.
7.	We have no responsibility to update our report referred to in paragraph 5 for events and circumstances occurring after the effective date of our report.
8.	Because the reserves data are based on judgments regarding future events, actual results will vary and the variations may be material.

Executed as to our report referred to above:

	NETHERLAND, SEWELL & ASSOCIATES, INC.
	Texas Registered Engineering Firm F-2699
	Dallas, Texas, USA
	March 6, 2026
	By:	/s/ Richard B. Talley, Jr.
		Richard B. Talley, Jr., P.E.
		Chairman and Chief Executive Officer

CBR:CDK

Exhibit 99.4

FORM 51-101F3

REPORT OF MANAGEMENT AND DIRECTORS ON RESERVES DATA AND OTHER INFORMATION

Management of Kolibri Global Energy Inc. (the “Company”) is responsible for the preparation and disclosure of information with respect to the Company’s oil and gas activities in accordance with securities regulatory requirements. This information includes reserve data.

An independent qualified reserve evaluator has evaluated and reviewed the Company’s reserves data. The report of the independent qualified reserves evaluators will be filed with securities regulatory authorities concurrently with this report.

The Reserves Committee of the Board of Directors of the Company has:

	1.	a) reviewed the Company’s procedures for providing information to the independent qualified reserves evaluator.
	2.	b) met with the independent qualified reserves evaluator to determine whether any restrictions affected the ability of the independent qualified reserves evaluator to report without reservation; and
	3.	c) reviewed the reserves data with management and the independent qualified reserves evaluator.

The Reserves Committee of the Board of Directors has reviewed the Company’s procedures for assembling and reporting other information associated with oil and gas activities and has reviewed that information with management. The Board of Directors has, on the recommendation of the Reserves Committee, approved:

	1.	a) the content and filing with securities regulatory authorities of Form 51-101F1 containing reserves data and other oil and gas information.
	2.	b) the filing of Form 51-101F2, which is the report of the independent qualified reserves evaluators on the reserves data; and
	3.	c) the content and filing of this report.

Because the reserves data are based on judgments regarding future events, actual results will vary and the variations may be material.

/s/ Wolf Regener

WOLF REGENER,

President & Chief Executive Officer

/s/ Gary Johnson

GARY JOHNSON,

Chief Financial Officer & Vice President

/s/ Leslie O’Connor

LESLIE O’CONNOR,

Director

/s/ Evan Templeton

EVAN TEMPLETON,

Director

Dated this 17^th day of March, 2026

FAQ

How much did Kolibri Global Energy (KGEI) increase its 2025 proved developed reserves?

Kolibri increased its 2025 proved developed producing reserves by 30%. Management attributes this gain to a successful 2025 drilling program in the Tishomingo Field, which added lower-risk producing barrels and helped offset the impact of lower oil price assumptions used in the independent reserve evaluation.

What are Kolibri Global Energy’s total proved and proved plus probable reserves for 2025?

Kolibri reports about 40.8 million BOE of proved reserves and 57.6 million BOE of proved plus probable reserves. These volumes are all in the Tishomingo Field in Oklahoma and were independently evaluated under forecast prices and costs as of December 31, 2025, using standard NI 51-101 methodologies.

What is the net present value of Kolibri Global Energy’s reserves at a 10% discount rate?

The before-tax NPV at 10% is $440.7 million for proved and $583.9 million for proved plus probable reserves. These valuations are based on forecast commodity prices and costs, including a 2026 WTI oil price assumption of $58 per barrel, and were prepared by Netherland, Sewell & Associates.

How did lower oil price assumptions affect Kolibri Global Energy’s reserve valuation?

Reserve value declined despite stronger volumes because the price deck was reduced. The 2026 oil price assumption fell to $58 per barrel from $76 per barrel in the prior report, which reduced net present values even though proved developed producing reserves and total proved reserves increased during 2025.

What were Kolibri Global Energy’s production and growth metrics for 2025?

Kolibri produced about 1.46 million BOE in 2025, averaging 4,013 BOEPD. Management highlights a 35% compound annual production growth rate over the last three years, supported by drilling seven and completing nine Caney wells in the Tishomingo Field during the year.

When will Kolibri Global Energy discuss its 2025 year-end results with investors?

Kolibri plans to release 2025 financial and operating results on March 19, 2026. On the same day, management will host an earnings conference call at 9:00 a.m. Pacific time, with both North American and international dial-in numbers available for investors and analysts.

Filing Exhibits & Attachments

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Press Releases

• EX-99.1 EX-99.1 80.7 KB
• EX-99.2 EX-99.2 272.3 KB
• EX-99.3 EX-99.3 27.1 KB
• EX-99.4 EX-99.4 16.4 KB
• EX-99 GRAPHIC 30.5 KB
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• EX-99 GRAPHIC 16.2 KB