Exhibit 96.2

Prepared for: enCore Energy Corp 101 N. Shoreline Blvd, Suite 450 Corpus Christi, Texas 78401 Prepared by: WWC Engineering 1849 Terra Avenue Sheridan, WY 82801 307-672- 0761 Principal Authors:    Christopher McDowell, P.G. & Ray Moores P.E.

This technical report titled “TECHNICAL REPORT ON THE GAS HILLS URANIUM PROJECT, FREMONT AND NATRONA COUNTIES, WYOMING, USA”, dated February 4, 2025, has been prepared under the supervision of, and signed by, the following Qualified Persons:

/s/ Christopher McDowell, P.G.

SME Registered Member, Registration No. 4311521

Professional Geologist, Wyoming No. 4135

/s/ Ray Moores, P.E.

Professional Engineer, Wyoming No. 10702

Gas Hills Uranium Project Technical Report – February 2025 Page i

TABLE OF CONTENTS

1.0		EXECUTIVE SUMMARY					1
		1.1		Background			1
		1.2		Mineral Resources			2
		1.3		Project			2
		1.4		Economic Analysis			5
		1.5		Conclusions and Recommendations			6
		1.6		Summary of Risks			6
2.0		INTRODUCTION					8
3.0		RELIANCE ON OTHER EXPERTS					10
4.0		PROPERTY DESCRIPTION AND LOCATION					11
		4.1		Property Description and Location			11
		4.2		enCore Acquisition of the Gas Hills Uranium Project			11
		4.3		Mining Claims			13
		4.4		State of Wyoming Lease, Private Mineral Lease, and Private Surface Use Agreement			13
		4.5		Permitting			14
		4.6		Environmental Liabilities			14
		4.7		Encumbrances and Risks			15
5.0		ACCESSIBILITY, CLIMATE, LOCAL RESOURCES, INFRASTRUCTURE, AND PHYSIOGRAPHY					16
		5.1		Accessibility			16
		5.2		Topography, Elevation, Physiography			16
		5.3		Climate, Vegetation and Wildlife			17
		5.4		Infrastructure			18
		5.5		Surface Rights			18
6.0		HISTORY					19
		6.1		Ownership and Control			19
		6.2		Historical Exploration and Mineral Resource Estimates			20
7.0		GEOLOGICAL SETTING AND MINERALIZATION					21
		7.1		Regional Geology			21
		7.2		Regional Stratigraphy			21
		7.3		Local Geologic Setting of the Gas Hills			22
		7.4		Local Mineralization in the Gas Hills			26
		7.5		Hydrogeology			30
		7.6		Geotechnical Testing			32

Gas Hills Uranium Project Technical Report – February 2025 Page ii

8.0  DEPOSIT TYPES		33
9.0  EXPLORATION		34
10.0  DRILLING		35
10.1  Drilling Methods		35
10.2  Drilling Length Versus True Thickness		36
10.3  Summary and Interpretation of Relevant Drill Results		36
11.0  SAMPLE PREPARATION, ANALYSES AND SECURITY		37
11.1  Radiometric Equivalent Geophysical Log Calibration		37
11.2  Pre-2007 Drilling Analyses		38
11.3  Post-2007 Drilling		39
11.4  Security		40
11.5  Summary		40
12.0  DATA VERIFICATION		41
12.1  Verification of Radiometric Database		41
12.2  Verification of Disequilibrium Factor		42
12.3  Verification of Pre-2007 Drilling by Re-Logging		43
12.4  Density of Mineralized Material		43
12.5  Summary		44
13.0  MINERAL PROCESSING AND METALLURGICAL TESTING		45
13.1  Uranium Extraction Bottle Roll Testing		45
13.2  Uranium Extraction Column Testing		45
13.3  IX Testing		46
13.4  Summary		46
14.0  MINERAL RESOURCE ESTIMATES		47
14.1  Mineral Resource Definitions		47
14.2  Basis of Mineral Resource Estimates		47
14.2.1   Methodology		47
14.3  Key Assumptions and Parameters		48
14.3.1   Cutoff Criteria		48
14.3.2   Bulk Density		49
14.3.3   Radiometric Equilibrium		49
14.4  Mineral Resource Summary		49
14.4.1   West Unit		51
14.4.2   Central Unit		52
14.4.3   Rock Hill		54
14.4.4   South Black Mountain		54
14.4.5   Jeep		55

Gas Hills Uranium Project Technical Report – February 2025 Page iii

14.5  GT Contour Maps		56
14.6  Discussion on Mineral Resources		56
15.0  MINERAL RESERVES		65
16.0  MINING METHODS		66
16.1  Mineral Deposit Amenability		66
16.2  Hydrology		67
16.2.1   Hydrogeology		67
16.2.2   Historical Drill Holes		69
16.3  Conceptual Wellfield Design		70
16.3.1   ISR Amenable Resources		70
16.3.2   Wellfield Patterns		71
16.3.3   Monitor Wells		72
16.3.4   Mining Schedule		72
16.4  Piping		74
16.5  Header Houses		74
16.6  Wellfield Reagents and Electricity		76
16.7  Mining Fleet Equipment and Machinery		76
16.8  Labor		76
17.0  RECOVERY METHODS		76
17.1  CPP Operations		76
17.2  Transportation		79
17.3  Energy, Water and Process Materials		79
17.4  Liquid Disposal		79
17.5  Solid Waste Disposal		80
18.0  PROJECT INFRASTRUCTURE		81
18.1  Roads		81
18.2  Electricity		81
18.3  Holding Pond		81
19.0  MARKET STUDIES AND CONTRACTS		82
20.0  ENVIRONMENTAL STUDIES, PERMITTING AND SOCIAL OR COMMUNITY
IMPACT		83
20.1  Environmental Studies		83
20.2  Waste Disposal and Monitoring		83
20.2.1   Waste Disposal		83
20.2.2   Site Monitoring		84
20.3  Permitting		84
20.4  Social or Community Impact		85

Gas Hills Uranium Project Technical Report – February 2025 Page iv

20.5  Project Closure		86
20.5.1   Byproduct Disposal		86
20.5.2   Well Abandonment / Groundwater Restoration		86
20.5.3   Demolition and Removal of Infrastructure		86
20.5.4   Site Grading and Revegetation		86
20.6  Financial Assurance		87
20.7  Adequacy of Current Plans		87
21.0  CAPITAL AND OPERATING COSTS		88
21.1  Capital Cost Estimation (CAPEX)		89
21.2  Operating Cost Estimation (OPEX)		91
22.0  ECONOMIC ANALYSIS		93
22.1  Assumptions		93
22.2  Cash Flow Forecast and Production Schedule		93
22.3  Taxation		96
23.0  ADJACENT PROPERTIES		98
24.0  OTHER RELEVANT DATA AND INFORMATION		99
25.0  INTERPRETATIONS AND CONCLUSIONS		100
25.1  Conclusions		100
25.2  Sensitivity Analysis		100
25.3  Risk Assessment		103
25.3.1   Resource and Recovery		103
25.3.2   Markets and Contracts		105
25.3.3   Operations		105
25.3.4   Permitting		106
25.3.5   Social and/or Political		107
26.0  RECOMMENDATIONS		108
27.0  REFERENCES		110

Gas Hills Uranium Project Technical Report – February 2025 Page v

LIST OF TABLES

Table 1.1.		Measured and Indicated Mineral Resource Summary			4
Table 1.2.		Inferred Mineral Resource Summary			4
Table 2.1.		Terms and Abbreviations			9
Table 5.1.		Climate Data			17
Table 10.1.		Drilling Summary by Area			35
Table 14.1.		Measured and Indicated Mineral Resource Summary			50
Table 14.2.		Inferred Mineral Resource Summary			50
Table 14.3.		West Unit Measured and Indicated Mineral Resource Summary			51
Table 14.4.		West Unit Inferred Mineral Resource Summary			52
Table 14.5.		Central Unit Measured and Indicated Mineral Resource Summary			53
Table 14.6.		Central Unit Inferred Mineral Resource Summary			53
Table 14.7.		Rock Hill Measured and Indicated Mineral Resource Summary			54
Table 14.8.		Rock Hill Inferred Mineral Resource Summary			54
Table 14.9.		South Black Mountain Measured and Indicated Mineral Resource Summary			55
Table 14.10.		South Black Mountain Inferred Mineral Resource Summary			55
Table 14.11.		Jeep Measured and Indicated Mineral Resource Summary			55
Table 14.12.		Jeep Inferred Mineral Resource Summary			56
Table 16.1.		Development Summary by Resource Area			72
Table 21.1.		CAPEX Cost Summary			90
Table 21.2.		Annual Operating Costs (OPEX) Summary			92
Table 22.1.		Cash Flow Statement			95
Table 22.2.		NPV Versus Discount Rate and IRR			96
Table 23.1.		Cameco Peach Project Mineral Resources			98

Gas Hills Uranium Project Technical Report – February 2025 Page vi

LIST OF FIGURES

Figure 4.1.		Location/Property Map			12
Figure 5.1.		Project Location and Wyoming Basins			16
Figure 7.1.		Gas Hills Uranium District Geologic Map			23
Figure 7.2.		Gas Hills Area Cross Sections			24
Figure 7.3.		Representative Stratigraphic Column			25
Figure 7.4.		Typical Uranium Roll-Front System			26
Figure 7.5.		Roll Front Exposed in Reclamation Channel, George-Ver Deposit			27
Figure 7.6.		Depiction of Multiple Stacked, En Echelon Uranium Deposits			29
Figure 7.7.		Gas Hills Uranium District			30
Figure 8.1.		Idealized Cross-Section of a Sandstone-Hosted Roll Front Uranium Deposit			33
Figure 14.1.		Resource Classification Boundaries			49
Figure 14.2.		West Unit A Sand GT Contour Map			57
Figure 14.3.		West Unit B Sand GT Contour Map			58
Figure 14.4.		Central Unit A Sand GT Contour Map			59
Figure 14.5.		Central Unit B Sand GT Contour Map			60
Figure 14.6.		Rock Hill GT Contour Map			61
Figure 14.7.		South Black Mountain A Sand GT Contour Map			62
Figure 14.8.		South Black Mountain B Sand GT Contour Map			63
Figure 14.9.		Jeep GT Contour Map			64
Figure 16.1.		Life of Mine Schedule			73
Figure 16.2.		Pipeline Infrastructure Map			75
Figure 17.1.		Process Flow Diagram			77
Figure 25.1.		Pre-Federal Income Tax NPV and IRR Sensitivity to Price			100
Figure 25.2.		Post-Federal Income Tax NPV Sensitivity to Price			101
Figure 25.3.		Pre-Federal Income Tax NPV Sensitivity CAPEX and OPEX			102
Figure 25.4.		Post-Federal Income Tax NPV Sensitivity CAPEX and OPEX			102

LIST OF APPENDICES

Appendix A		Certificate of Qualified Persons
Appendix B		List of Lode Claims and State Leases

Gas Hills Uranium Project Technical Report – February 2025 Page vii

1.0 EXECUTIVE SUMMARY

1.1 Background

This independent Technical Report (the Report) was prepared by Christopher McDowell P.G. and Ray Moores P.E. (The Authors) of Western Water Consultants d/b/a WWC Engineering (WWC) for enCore Energy Corp. (enCore) in accordance with National Instrument 43-101, Standards of Disclosure for Mineral Projects (NI 43-101 Standards) and the Modernized Property Disclosure Requirements for Mining Registrants as described in Subpart 229.1300 of Regulation S-K (S-K 1300). The effective date of this report is December 31, 2024.

The purpose of this Report is to disclose the results of a Preliminary Economic Assessment (PEA) for the Gas Hills Uranium Project (the Project). The term PEA in the Report is consistent with an Initial Assessment (IA) with economics under S-K 1300. Mr. McDowell and Mr. Moores are Qualified Persons (QPs) under NI 43-101 and S-K 1300.

The Project is owned by UColo Exploration Corp. (UColo), a Utah corporation, and a wholly owned subsidiary of URZ Energy Corp. (URZ). URZ is a wholly owned subsidiary of Azarga Uranium Corp. (Azarga) which is a wholly owned subsidiary of enCore. Surface land ownership at the Project is predominantly managed by the U.S. Department of Interior, Bureau of Land Management (BLM) and the minority of the land is owned by the State of Wyoming and private landowners. Mineral ownership at the Project is a combination of federal, state of Wyoming, and private (fee) ownership.

A report titled NI 43-101 Technical Report Preliminary Economic Assessment, Gas Hills Uranium Project, Fremont and Natrona Counties, Wyoming, USA with an effective date of June 28, 2021 was previously prepared by Roughstock Mining Services (Roughstock) and WWC (Roughstock & WWC 2021). WWC was retained by enCore to prepare this independent Report for the in-situ recovery (ISR) amenable resources of the Project.

Between 1953 and 1988 many companies explored, developed, and produced uranium in the Gas Hills, including on lands now controlled by enCore. Three uranium mills operated in the district and two others nearby were also fed by ore mined from Gas Hills. Cumulative production from the Gas Hills is in excess of 100 million pounds of uranium, mainly from open-pit mining, but also from underground mining and ISR (Beahm, 2017).

Available data utilized in this Report includes pre-2007 exploration and production on enCore’s Gas Hills Uranium Project, and drilling completed by a previous owner, Strathmore Minerals Corporation, from 2007 to June 2013. In August 2013, Strathmore Minerals Corporation was acquired by Energy Fuels Inc. (Energy Fuels), who subsequently sold the Project to URZ in October 2016. Azarga acquired the Project when it merged with URZ in July 2018 and enCore acquired the Project when it merged with Azarga in December 2021.

Gas Hills Uranium Project Technical Report – February 2025 Page 1

Data sources for the estimation of uranium mineral resources for the Project include radiometric equivalent data (eU₃O₈) for 4,570 drill holes, and eU₃O₈ and Prompt Fission Neutron (PFN) logging data for 272 drill holes. The intent of recent drilling between 2007 and 2024 included verification of earlier data for drill holes and other exploration results.

Metallurgical studies were completed on recovered materials including bulk samples from reverse circulation drilling and cored sections. Bottle roll and column leach tests indicate uranium recoveries of approximately 90 percent and sulfuric acid consumption of approximately 55 pounds per ton treated, which is consistent with past mining results.

1.2 Mineral Resources

The mineral resource estimation method utilized in this Report is the Grade Thickness (GT) contour method. This method is considered appropriate for this type of deposit.

Mineral resources were estimated using a cutoff grade of 0.02% eU₃O₈. Estimated mineral resources are summarized in Table 1.1 using a 0.10 GT cutoff. The 0.10 GT base case cutoffs were selected by meeting economic criteria for both ISR and non-ISR resources differentiated on the relative location to the water table. Resources labeled “ISR” meet the criteria of being sufficiently below the water table to be amenable for extraction by ISR methods and as well as also meeting other hydrogeological criteria. “non-ISR” resources include those generally above the natural water table, which would typically be mined using open pit methods. The average grade of ISR resources in this estimate at a 0.10 GT cutoff met economic criteria for ISR extraction, and thus is considered the base case for this Report.

Section 14.0 provides additional details regarding the determination of cutoff grade, GT cutoff, and the assessment of reasonable prospects for economic extraction of the mineral resource.

1.3 Project

The Project consists of four resource areas that contain ISR amenable resources named by enCore as the West Unit, Central Unit, South Black Mountain, and Jeep. There is an additional non-ISR amenable resource area at the Project named the Rock Hill Unit as well as other shallow areas with resources located above the water table that were not considered in the economic assessment portion of this Report. For the purposes of this Report, uranium recovery was estimated at 6,164,000 lbs at a production rate of 1.0 million pounds U₃O₈ per year with a long-term uranium price of USD $87.00/lb using a low pH lixiviant.

Labor for the Project will likely come from nearby population centers of Jeffery City, Casper, Riverton, and Rawlins, WY. The Project is accessible via gravel roads and year-round access should not be a problem. The Project is situated near electric transmission lines and access to power is not anticipated to be a problem. As discussed in Section

Gas Hills Uranium Project Technical Report – February 2025 Page 2

18.0, appropriate resources, manpower, and access are available to provide services to the Project.

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Table 1.1. Measured and Indicated Mineral Resource Summary

December 31, 2024 (GT cutoff 0.10)
		Pounds		Tons		Avg. Grade		Avg. Thickness		Avg. GT
Measured		2,051,000		994,000		0.10%		5.35		0.552
Indicated		8,713,000		6,031,000		0.07%		6.13		0.443
Total M&I		10,764,000		7,025,000		0.08%		6.05		0.463
December 31, 2024, ISR Only (GT cutoff 0.10)
		Pounds		Tons		Avg. Grade		Avg. Thickness		Avg. GT
Measured		2,051,000		994,000		0.10%		5.35		0.552
Indicated		5,654,000		2,835,000		0.10%		4.92		0.491
Total M&I		7,705,000		3,829,000		0.10%		4.99		0.502
December 31, 2024, Non-ISR Only (GT cutoff 0.10)
		Pounds		Tons		Avg. Grade		Avg. Thickness		Avg. GT
Indicated		3,059,000		3,196,000		0.05%		8.6		0.412
Total M&I		3,059,000		3,196,000		0.05%		8.6		0.412

Notes:

1. Mineral resources as defined in 17 CFR § 229.1300 and as used in NI 43-101.

2. All ISR Only resources occur below the static water table.

3. The point of reference for mineral resources is in-situ at the Project.

4. Mineral resources that are not mineral reserves do not have demonstrated economic viability.

5. An 80% metallurgical recovery factor was considered for the purposes of the economic analysis.

6. Totals may not sum due to rounding.

Table 1.2. Inferred Mineral Resource Summary

December 31, 2024 (GT cutoff 0.10)
		Pounds		Tons		Avg. Grade		Avg. Thickness		Avg. GT
Inferred		490,000		514,000		0.05%		6.16		0.293
December 31, 2024, ISR Only (GT cutoff 0.10)
		Pounds		Tons		Avg. Grade		Avg. Thickness		Avg. GT
Inferred		428,000		409,000		0.05%		5.94		0.31
December 31, 2024, Non-ISR Only (GT cutoff 0.10)
		Pounds		Tons		Avg. Grade		Avg. Thickness		Avg. GT
Inferred		62,000		105,000		0.03%		7.01		0.208

Notes:

1. Mineral resources as defined in 17 CFR § 229.1300 and as used in NI 43-101.

2. All ISR Only resources occur below the static water table.

3. The point of reference for mineral resources is in-situ at the Project.

4. Mineral resources that are not mineral reserves do not have demonstrated economic viability.

5. Totals may not sum due to rounding

Gas Hills Uranium Project Technical Report – February 2025 Page 4

The proposed wellfields consist of a combination of 5-spot and 7-spot well patterns with an average pattern area of approximately 17,000 ft². Header houses will be installed in the wellfields and each header house will operate approximately 75 wells. A central processing plant (CPP) will be located at the West Unit and be connected to the other resource area by high density polyethylene (HDPE) pipelines to transport lixiviant to the CPP for processing. A discussion of wellfields and header houses is located in Section 16.0 and the discussion of the CPP is located in Section 17.0.

Production will generally occur at each resource area consecutively and production will occur over a period of approximately seven years. Groundwater restoration, decommissioning, and reclamation will be implemented at each resource area immediately following the production period. The overall life of mine is approximately 11 years from initiation of construction activities to the completion of surface reclamation. The mine schedule is discussed in Section 16.0.

1.4 Economic Analysis

This Report indicates a pre-tax NPV of $166.9 million at an 8 percent discount rate with an IRR of 54.8 percent compared to an after-tax NPV of $141.8 million at an 8 percent discount rate with an IRR of 50.2 percent. The NPV assumes cash flows take place in the middle of each period. The NPV and IRR calculations are based on Year-2 through Year 11 and includes costs escalated by 8 percent per year from Year -4 and Year -3 treated as if the escalated costs occurred in Year-2. This approach to calculating the IRR and NPV was taken because Year -2 is the first year that a significant sum of capital is invested into the Project.

The mine plan and economic analysis are based on the following assumptions:

• A recovery factor of 80 percent of the measured and indicated mineral resource (no inferred mineral resource is included),

• A U₃O₈ sales price of $87.00/lb,

• A mine life of 11 years,

• A pre-income tax cost including royalties, state and local taxes, operating costs, and capital costs of $40.61/lb, and

• Initial capital costs of $55.2 million.

Costs for the Project are based on economic analyses for similar ISR uranium projects in the Wyoming region as well as WWC’s in-house experience with mining and construction costs. All costs are in U.S. dollars (USD). To date, no detailed design work has been completed for the wellfields or the CPP. The Authors believe that general industry costs from similar projects adequately provide a ± 30 percent cost accuracy

Gas Hills Uranium Project Technical Report – February 2025 Page 5

which is in accordance with industry standards for a PEA and complies with item 1302 of Regulation S-K for an Initial Assessment with economics.

As additional data are collected for the Project and the wellfield and plant designs are advanced, estimates can be refined.

This analysis is based on measured and indicated mineral resource and does not include the inferred mineral resource. Mineral resources that are not mineral reserves do not have demonstrated economic viability. Given the speculative nature of mineral resources, there is no guarantee that any or all of the mineral resources included in this Report will be recovered. This Report is preliminary in nature and there is no certainty that the Project will be realized.

1.5 Conclusions and Recommendations

The Authors conclude that the ISR amenable mineral resources as determined by this report show sufficient economic and technical viability to move to the next stage of development.

Due to the lack of current data on alternative lixiviants and consistent with enCore’s significant experience utilizing alkaline based lixiviants at their projects, the Authors recommend completing additional metallurgical studies and leach testing utilizing an alkaline based lixiviant.

The Authors recommend initiating permitting of the Project, especially as much of the work was previously completed for a mine application prepared for the Project in 2013 by Strathmore Minerals Corporation. The Authors’ recommendations for additional work programs are described in Section 26.0.

1.6 Summary of Risks

The Project is located in a brownfield district where the geology is well-known and past mining and milling have successfully been completed.

The Project does have some risks similar in nature to other mineral projects and uranium projects in particular. Some risks are summarized below and are discussed in detail in Section 25.0:

• Variance in the grade and continuity of mineralization from what was interpreted by drilling and estimation techniques,

• Environmental, social and political acceptance of the Project could cause delays in conducting work or increase the costs from what is assumed,

• Risk associated with delays or additional requirements for regulatory authorizations,

• Risk associated with the uranium market and sales contract,

Gas Hills Uranium Project Technical Report – February 2025 Page 6

• Risk associated with uranium recovery and processing,

• Changes in the mining and mineral processing recovery, and

• Due to limited testing and operation of ISR throughout the Project, ISR operations may not be able to be successfully implemented due to hydrogeological, environmental, or other technical issues.

With regard to the socio-economic and political environment of the Gas Hills Uranium Project area, Wyoming mines have produced over 200 million pounds of uranium from both conventional and ISR mine and mill operations. Production began in the early 1950’s and continues to the present. The state has ranked as the number one US producer of uranium since 1994. Wyoming is considered generally favorable to mine development and provides a well-established environmental regulatory framework for ISR which has been conducted in the state since the 1960’s.

To the Authors’ knowledge there are no other significant risks that could materially affect the Report or interfere with the recommended work programs.

Gas Hills Uranium Project Technical Report – February 2025 Page 7

2.0 INTRODUCTION

This report titled “TECHNICAL REPORT ON THE GAS HILLS URANIUM PROJECT, FREMONT AND NATRONA COUNTIES, WYOMING, USA” was prepared for enCore Energy Corp. in accordance with NI 43-101 and S-K 1300 Standards. The effective date of this Report is December 31, 2024.

This independent Report was prepared for enCore by WWC under the supervision of Christopher McDowell, P.G. and Ray Moores P.E. A NI 43-101 PEA was previously prepared by Roughstock and WWC with an effective date of June 28, 2021 (Roughstock & WWC 2021). This Report is intended to state the mineral resource estimate and calculate the capital and operating cost estimates and economic analysis with the most recent market information.

enCore is incorporated in the Province of British Columbia, with the principal office located at 101 N Shoreline Blvd, Suite 450, Corpus Christi, TX 78401.

Data sources for the estimation of uranium mineral resources for the Project include radiometric equivalent data (eU₃O₈) for 4,570 drill holes (4,056 pre-2007), eU₃O₈ and PFN logging data for 272 drill holes completed between 2007 and 2013, and eU₃O₈ and core data for a core hole completed in 2024.

Units of measurement unless otherwise indicated are feet (ft), miles, acres, pounds (lbs), and short tons (2,000 lbs). Uranium production is expressed as pounds U₃O₈, the standard market unit. ISR refers to in-situ recovery, sometimes also termed in-situ leach (ISL). Unless otherwise indicated, all references to dollars ($) refer to United States currency. Table 2.1 provides a brief list of the terms, abbreviations, and conversion factors used in this Report.

Christopher McDowell, P.G. is the independent qualified person responsible for the preparation of this Report and the mineral resource estimates herein. Mr. McDowell is a Qualified Person (QP) under NI 43-101 and S-K 1300 Standards responsible for the content of this Report and a Professional Geologist with 9 years of professional experience in uranium geology and ISR uranium mining. Mr. McDowell is responsible for development of sections 1-15 and 23-27 of this Report.

Ray Moores, P.E. is the independent qualified person responsible for the preparation for this Report and the technical and economic analysis herein. Mr. Moores is a QP under NI 43-101 and S-K 1300 Standards with 22 years of industry experience including 16 years direct experience with ISR uranium mining, permitting, and licensing. Mr. Moores is responsible for development of sections 1-5, 16-22, and 24-27 of this Report.

Christopher McDowell, P.G. and Ray Moores P.E. conducted a current site visit on May 24, 2021. The purpose of the visit was to observe the geology of the site, review site activities, observe potential locations of Project infrastructure, understand the location of historic exploration and mining activities, and gain knowledge on existing site infrastructure.

Gas Hills Uranium Project Technical Report – February 2025 Page 8

Table 2.1. Terms and Abbreviations

Uranium Specific Terms and Abbreviations
Grade		parts per million		ppm U3O8		weight percent		% U3O8
Radiometric Equivalent Grade				ppm eU3O8				% eU3O8
Thickness		meters		m		feet		ft
Grade Thickness Product		grade x meters		GT (m)		grade x feet		GT (ft)
Headgrade		milligrams per liter		Mg/L

General Terms and Abbreviations
		Metric				US				Metric to US Conversion
		Term		Abbreviation		Term		Abbreviation
Area		Square Meters		m2		Square Feet		ft2		10.76
		Hectare		Ha		Acre		Ac		2.47
Volume		Cubic Meters		m3		Cubic Yards		Cy		1.308
Length		Meter		m		Feet		ft		3.28
		Meter		m		Yard		Yd		1.09
Distance		Kilometer		km		Mile		mile		0.6214
Weight		Kilogram		kg		Pound		Lb		2.20
		Metric Tonne		Tonne		Short Ton		Ton		1.10

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3.0 RELIANCE ON OTHER EXPERTS

The Authors have fully relied upon information on uranium commodity price forecasts from TradeTech’s 4^th quarter 2023 market Outlook Report. This information is used in Section 19.0 of this Report. WWC Engineering received this information from enCore in November 2024.

The Authors have relied on information provided by enCore regarding property ownership, title, and mineral rights; regulatory status and environmental information, including liabilities on the Project.

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4.0 PROPERTY DESCRIPTION AND LOCATION

4.1 Property Description and Location

enCore’s 100 percent owned Gas Hills Uranium Project is located approximately 45 miles east of Riverton, Wyoming in the historic Gas Hills Uranium District. The Project and the Gas Hills Uranium District are located along the southern extent of the Wind River Basin, near the northern edge of the Granite Mountains. The company’s Project properties, including the West Unit, Central Unit, Rock Hill, South Black Mountain, and Jeep properties, consist of 628 unpatented lode mining claims, one State of Wyoming mineral lease, one private mineral lease, and one private surface use agreement. Together the properties encompass approximately 360 surface acres and 12,960 mineral acres. As shown on Figure 4.1 Location/Property Map, the properties are located at latitude 42.7295°, longitude -107.6596° in Townships 32 and 33 North, Ranges 89, 90 and 91 West, 6^th Principal Meridian, Fremont and Natrona Counties, Wyoming.

The US federal government owns the minerals associated with the mining claims, the State of Wyoming owns the minerals and surface associated with the State lease, the South Pass Land and Livestock Company owns the minerals associated with the private mineral lease, and the Philp Sheep Company owns the surface associated with the private surface use agreement. The BLM manages the claims on behalf of the US federal government.

The mining claims, State lease, and private mineral lease were assembled by Strathmore Resources (US) Ltd. (Strathmore) between April 2006 and September 2012 and sold to UColo on October 31, 2016. Title has remained in UColo’s name since that date and UColo is a subsidiary of enCore. The surface use agreement was entered into by UColo effective July 7, 2023.

4.2 enCore Acquisition of the Gas Hills Uranium Project

On September 9, 2016, URZ’s subsidiary, UColo, entered into an Asset Purchase and Sale Agreement (APA) with Strathmore, a wholly owned subsidiary of Energy Fuels, whereby URZ purchased all of Strathmore’s interest in the Project. In addition to the Project, the APA transaction included URZ’s purchase of Strathmore’s claims and State mineral leases for the Juniper Ridge and Shirley Basin Properties, however, these two properties are not discussed in this Report. The transaction closed on October 31, 2016.

On May 7, 2018, Azarga and URZ announced an agreement to merge under a plan of arrangement. On June 29, 2018, the shareholders of both URZ and Azarga approved the merger and on July 5, 2018 the merger was completed. As a result, URZ became a wholly owned subsidiary of Azarga. On December 31, 2021, the shareholder approved merger of Azarga and enCore closed and Azarga became a wholly owned subsidiary of enCore.

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Figure 4.1. Location/Property Map

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4.3 Mining Claims

Approximately 12,560 mineral acres are encompassed by the Project claims. A 5 percent net proceeds royalty applies to 172 of the 628 claims as follows:

• A net proceeds royalty of 5 percent on 155 claims was granted by Quit Claim Deed from Strathmore to Elmhurst Financial Group, Inc. on October 31, 2007. One of the claims was relinquished during Strathmore’s ownership. The surviving 154 claims were sold to UColo and remain subject to the 5 percent net proceeds royalty.

• A 5 percent net proceeds royalty was granted by Assignment from Strathmore to Blue Rock on October 31, 2007 on nine full claims and on the southern 720 feet of nine additional claims. The 18 claims were sold to UColo and remain subject to the 5 percent net proceeds royalty.

The other 456 claims are not subject to royalties or other encumbrances.

UColo has possessory right to explore, develop and produce from the unpatented lode mining claim areas and must pay an annual maintenance fee to the BLM of $200.00 per claim on or before September 1 each year. Surface use at the location of the mining claims on BLM lands is allowed subject to Title 43 of the US Code of Federal Regulations Subpart 3809 and requires permitting by both the BLM and the State of Wyoming Department of Environmental Quality, Land Quality Division (WDEQ-LQD). A list of claim numbers and names is included in Appendix B.

4.4 State of Wyoming Lease, Private Mineral Lease, and Private Surface Use Agreement

State of Wyoming Lease

Strathmore entered into a ten-year lease with the State of Wyoming for Mineral Lease #0-42121 on April 2, 2007. The lease was subsequently transferred by Assignment from Strathmore to UColo on October 31, 2016. UColo renewed the lease before its 10-year expiration, extending the lease an additional ten years to April 1, 2027. The lease can be renewed, at UColo’s option, for unlimited additional 10-year periods as long as the terms and conditions of the lease have been met up to the time of applying to the State of Wyoming for renewal. The lease encompasses approximately 320 surface acres and 320 mineral acres in the NE¹⁄₄, N¹⁄₂NW¹⁄₄, and E¹⁄₂SE¹⁄₄ of Section 36, Township 33 North, Range 90 West, 6^th Principal Meridian, Fremont County, Wyoming. The lease grants to the State a royalty of 4 percent of the gross selling price of U₃O₈ or $5.00 per leased acre per year, whichever is more. No mineral resources in this Report are located on this lease.

Private Mineral Lease

Strathmore entered into a private mineral lease with South Pass Land and Livestock Company on July 28, 2010 for rights to minerals on the following two parcels of land: 40 mineral acres in the Jeep area in the SE¹⁄₄SE¹⁄₄ of Section 32, Township 32 North,

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Range 91 West, 6^th Principal Meridian, Fremont County, Wyoming and 40 mineral acres in the West Unit area in the SW¹⁄₄SW¹⁄₄ of Section 19, Township 32 North, Range 90 West, 6^th Principal Meridian, Fremont County, Wyoming. The mineral lease was transferred by Assignment and Assumption of Mineral Lease from Strathmore to UColo on October 31, 2016. UColo exercised its option to renew the lease for an additional 10 years in July 2020 by making the required payment. Unlimited 10-year renewals are available at UColo’s option for additional payments. The lease grants a 5 percent net proceeds royalty to the owner of the mineral properties. The surface is owned separately from South Pass Land and Livestock Company. An agreement for surface access at the West Unit is described below. Presently, there is no agreement for surface access at the Jeep parcel.

Private Surface Use Agreement

UColo entered into a private surface use and access agreement with Philp Sheep Company on July 7, 2023 to access and use approximately 40 surface acres in the West Unit located in the SW1/4SW1/4 of Section 19, Township 32 North, Range 90 West, 6^th Principal Meridian, Fremont County, Wyoming. The agreement allows exploring, prospecting, drilling, constructing, and plugging and abandoning up to 10 exploratory boreholes on the parcel. Access to Section 19 is provided across the SW¹⁄₄SW¹⁄₄ of Section 13, Township 32 North, Range 91 West, 6^th Principal Meridian, Fremont County, Wyoming under the agreement. The term of the agreement is through November 7, 2025. Philp Sheep Company does not own the minerals in the parcel covered by the agreement. The minerals are owned by the South Pass Land and Livestock Company described above.

4.5 Permitting

enCore has an approved Drilling Notification (DN0369) that allows surface use for the purposes of exploration by drilling.

Although not required at this stage, mine development would require a number of permits depending on the type and extent of development, the most significant permits being the Permit to Mine, the Source Materials License issued by the WDEQ-LQD as required for mineral processing of natural uranium, and an approved Plan of Operations issued by the BLM. Any injection or pumping operations for in situ mining operations will require permits from the WDEQ which has authority under the Safe Water Drinking Act that stems from a grant of primacy from the US Environmental Protection Agency for administering underground injection control programs in Wyoming.

4.6 Environmental Liabilities

To the Author’s knowledge, no specific environmental liabilities are known to exist. There is a DN bond for exploration previously held by URZ in the amount of $100,000 which has been assumed by enCore. This bond is subject to annual renewal and updating.

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There are significant previous surface disturbances adjacent to the properties including drill roads, drill sites, haul roads, spoil dumps, reclaimed mill sites, and mined open pits.

Several legacy reclamation programs are ongoing in the Gas Hills, including on lands controlled by enCore. These programs are authorized under the Surface Mining and Reclamation Control Act of 1977 and carried out by the Wyoming Department of Environmental Quality/Abandoned Mine Lands Division (WDEQ-AML) with cooperation of the BLM. In addition, several former mill tailings sites on adjacent lands have been or will be reclaimed and transferred to the US Department of Energy (the US DOE) for long-term care and maintenance.

All of this reclamation activity is currently being performed at the sole cost of the state and federal government agencies. State of Wyoming mining regulations will require enCore to reclaim any new mining activities but excludes enCore from any environmental liability associated with historical mining on enCore’s controlled lands.

Strathmore submitted a Permit to Mine application with the WDEQ-LQD on August 28, 2013 (Strathmore, 2013). The Permit to Mine application was subsequently withdrawn by Energy Fuels following their acquisition of Strathmore. It is possible that much of this data can be utilized in a new Permit to Mine application should that be considered in the future. Although collection of additional baseline data will be necessary for a new permit submittal.

4.7 Encumbrances and Risks

The unpatented lode mining claims will remain the property of enCore provided it adheres to required filing and annual payment requirements with Fremont and Natrona Counties and the BLM. Legal surveys of unpatented lode mining claims are not required and are not known to have been completed. Mining claims are subject to the Mining Law of 1872. Changes in the mining law could affect the Project.

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5.0 ACCESSIBILITY, CLIMATE, LOCAL RESOURCES, INFRASTRUCTURE, AND PHYSIOGRAPHY

5.1 Accessibility

The Gas Hills Uranium District can be accessed by traveling southeast of Riverton approximately 45 miles along Wyoming State Highway 136 (Gas Hills Road) to the junction of Fremont County Road #5 (Ore Haul Road). Access from Casper is approximately 47 miles west on US Highway 20/26 until the Waltman Junction then south onto Natrona County Road 212 (Gas Hills Road) it is approximately 22 miles to the northeast corner of the district. Access from the south is from US Highway 287 at Jeffrey City by traveling north along Fremont County Road #5 approximately 15 miles to the southwestern corner of the district. Regional airports are located in Casper and Riverton and a BNSF railroad passes through Casper and Powder River, WY, approximately 40 miles northeast of the Project.

Figure 5.1. Project Location and Wyoming Basins

5.2 Topography, Elevation, Physiography

The Project is located within the Wyoming Basin physiographic province (Figure 5.1) along the southern flank of the Wind River Basin which is a northwest-southeast trending, intermountain, structurally bounded basin. The basin is bounded on the west

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by the Wind River Range, on the east by the Casper Arch, and on the north by the Owl Creek, Washakie and Bighorn Mountains. In the Gas Hills, Beaver Rim, the southern escarpment of the Wind River Basin, is located at the northern margin of Sweetwater Plateau, separating the drainages between the Wind and Sweetwater Rivers. Elevations in the Gas Hills vary from a low of approximately 6,300 feet at the northwestern extent to a high in excess of 7,400 feet atop Beaver Rim.

5.3 Climate, Vegetation and Wildlife

Climate in the Gas Hills is continental semi-arid, with annual precipitation of 8-12 inches, mostly falling in the form of late autumnal to early spring snows. The summer months are usually hot with temperature occasionally exceeding 100^oF, dry and clear except for infrequent rains. Winter conditions can be severe and can include sub-zero temperatures and ground blizzards. Most drainages in the area are ephemeral, flowing only during storm events or spring snow melt. Year round open-pit mining operations were successfully carried out previously in the Gas Hills district. The principal access to the Project is Wyoming Highway 136 which is paved and maintained year-round. The secondary access is the Gas Hills Road which is a gravel county road. Portions of the Gas Hills Road are not currently maintained on a year-round basis but have been in the past. In sum year-round operations can be conducted at the Project. The climate in the Gas Hills is most similar to that of Casper Wyoming, some 60 miles to the northeast for which a brief summary of weather conditions is provided in Table 5.1.

Table 5.1. Climate Data

Measurement		Climate Data
Average annual high temperature		59°F
Average annual low temperature		31°F
Average annual precipitation - rainfall		12.42 inches
Average annual precipitation - snowfall		75 inches*

*Snowfall depth is aggregate snowfall over the season, actual snow depth experienced on the ground at any one time is typically less due to snow melting throughout the season.

(Climate Casper - Wyoming and Weather averages Casper (US Climate Data, 2021))

Most common native vegetation is sage brush and prairie grasses and to a lesser extent, rabbit brush. No threatened or endangered plants are known in the area. Limited upland areas have juniper and limber pine trees on north facing slopes.

Mule deer and pronghorn antelope are common, as are nesting raptors. Small rodents and rabbits are common. The greater sage-grouse, present in the general area of the Project, has been considered for listing as a threatened or endangered species. Successful and ongoing mitigation efforts by the State of Wyoming have significantly decreased the probability of regulatory listing of the sage grouse.

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5.4 Infrastructure

Extensive production in Wyoming of minerals (coal, trona, uranium) and oil/gas has provided a highly skilled labor force in the region. Population centers within two hours of the Project include Casper, Riverton, Lander, and Rawlins, where equipment and supplies may be obtained. Paved roads from these towns and cities extend to the edge of the Project area. Access and haul roads within the Project are graded gravel and are maintained by the State, County, and mining companies operating in the area. Functioning power lines, natural gas lines, telephone lines, and fiber optic cable are present on and near enCore’s properties. Several wells producing water for domestic and industrial use are also on or close to enCore’s properties. It is the Author’s opinion that the Property area controlled by enCore is more than adequate to provide areas for potential mining operations and associated facilities and for mineral processing operations.

5.5 Surface Rights

The 1872 Mining Law grants certain surface rights along with the right to mine provided the surface use is incident to the mine operations. In order to exercise those rights, the operator must comply with a variety of State and Federal regulations (refer to Section 20.0). For areas of private surface ownership appropriate surface-owner agreements would be required.

The Code of Federal Regulations 43 CFR 3715 governs the use and occupancy under the mining laws for Federal Lands. Under these regulations, 3715.05, states “Mining operations means all functions, work, facilities, and activities reasonably incident to mining or processing of mineral deposits.” For future mining and mineral processing, the Author concludes that enCore through UColo has, or can obtain through permitting and licensing of site activities, sufficient surface rights for possible future mining operations.

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6.0 HISTORY

The Gas Hills Uranium District (Gas Hills) was one of the major uranium mining and production regions in the USA. Early discoveries were based on both ground and aerial radiometric surveys in 1953. The initial discovery of uranium in the Gas Hills is credited to Neil MacNeice who located a mineralized outcrop using a handheld radiometric counter while Antelope hunting in the area on September 13, 1953 (Snow, 1978). During approximately the same time period, aerial radiometric surveys conducted on behalf of the Globe Mining Company identified radiometric anomalies in Gas Hills area as well. Between 1953 and 1988 many companies explored, developed, and produced uranium in the Gas Hills, including on lands now controlled by enCore.

Three uranium mills operated in the district and two others nearby were also fed by ore mined from Gas Hills. Cumulative production from the Gas Hills is in excess of 100 million pounds of uranium, mainly from open-pit mining, but also from underground mining and ISR.

Mine production did occur adjacent to and in the vicinity of the Project; however, the areas for which mineral resources are defined are unmined. Uranium was discovered in the Gas Hills in September 1953 by both ground and airborne radiometric surveys. Early exploration in the district exposed numerous near surface oxidized deposits and small shipments of ore were shipped out of state for processing. In 1955, the Atomic Energy Commission (AEC now the US DOE) constructed an ore buying station in Riverton, WY where ore was stockpiled and eventually milled. In the Gas Hills area, when the AEC approved purchase allotments in 1956, Utah Construction (later Pathfinder and then Areva) began the Lucky Mc Mill in the central Gas Hills and Lost Creek Oil and Uranium (later Western Nuclear) began the Split Rock Mill 15 miles south at Jeffrey City. By 1959 the AEC authorized three additional mills in the county: Fremont Minerals’ (Susquehanna Mining) mill in Riverton, Federal-Radorock-Gas Hills Partners’ (later Federal American Partners) central Gas Hills mill, and Globe Uranium Company’s (later Union Carbide) east Gas Hills mill.

With the rapid decline in uranium price in the early to mid-1980’s production slowly halted. The last mill production in the Gas Hills occurred in 1988 at Lucky Mc. Extensive mill site and mine reclamation occurred from the late 1980s through to the present time in the Gas Hills. However, Wyoming remains the largest current uranium producer in the USA and there are numerous uranium projects in the state (Beahm, 2017).

6.1 Ownership and Control

The present Project area was acquired by URZ’s subsidiary UColo from Strathmore on October 31, 2016 and subsequently the Project area was acquired by enCore through a merger with Azarga in 2021. The minerals were originally acquired by staking and purchasing unpatented mining claims, and by acquiring the State of Wyoming Mineral Lease and the private South Pass Land and Livestock Company mineral lease.

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6.2 Historical Exploration and Mineral Resource Estimates

Historical mineral resources were generated by several sources including data from mining companies and/or their consultants that were active in the area historically including American Nuclear Corporation, 1985, Anonymous report, 1979, Dames & Moore, 1976, David Robertson & Associates, 1979, Energy Fuels, 1978, and Mullen Mining, 1977. The authors of this Report did not review all of these historical estimates but focused on more recent estimates including those prepared by Roughstock, Beahm, 2017 and CAM, 2013.

More than 100,000 exploration and development holes were drilled in the Gas Hills from the mid-1950s to the mid-1980s. Since 1990, a few hundred holes have been drilled, nearly all by Strathmore and Cameco. Strathmore acquired exploration data for several of its Gas Hills properties; all of which are now controlled by enCore.

The most recent previous resource estimate was completed by Roughstock in the report “NI 43-101 TECHNICAL REPORT, PRELIMINARY ECONOMIC ASSESSMENT, GAS HILLS URANIUM PROJECT, FREMONT AND NATRONA COUNTIES, WYOMING, USA” dated effective June 28, 2021.

Previous resource estimates are not relevant since there is a current mineral resource estimate on the Project which is described in Section 14.0 of this Report.

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7.0 GEOLOGICAL SETTING AND MINERALIZATION

7.1 Regional Geology

The Gas Hills Uranium District is located in the south-central portion of the Wind River Basin as depicted on Figure 5.1. The district occupies approximately 100 square miles along the south-central flank of the Wind River Basin in central Wyoming. The Wind River Basin is marked by a northwest-trending topographic depression surrounded by mountains on all but the eastern side. To the south, the Wind River Basin is bounded by the Beaver Rim, which is an erosional scarp. This topographic feature forms a boundary between the Wind River Basin to the north and the Sweetwater Basin and Granite Mountains to the south.

East of the Gas Hills District is a northwest-trending structural high, known as the Rattlesnake Hills Anticline. Rocks ranging in age from the Precambrian to the Paleocene are exposed along the northeastern flank of this feature. Mountain ranges around the Wind River Basin were uplifted during the late Cretaceous to early Tertiary Laramide orogeny. Erosion from these uplifts deposited terrestrial clastic sediments of the Eocene Wind River Formation unconformably upon tilted and deformed Paleozoic-Mesozoic rocks. Arkosic sandstones and conglomerates are common in the Wind River Formation, indicative of their alluvial fan depositional setting. The Tertiary sediments are typically range between 400-1,000 feet thick in the Gas Hills area (Strathmore 2013) and pinch out against Paleozoic/Mesozoic rocks south of the Gas Hills.

Sometime during late Tertiary time, the Granite Mountain block dropped down along east-west faults that lie between the mountains and the Gas Hills and associated faults near the Green Mountain-Crook Mountains south of Jeffrey City, forming the Split Rock syncline. This down dropping resulted in a southward regional tilt of the Wind River sedimentary rocks of 2-6° in the Gas Hills (Beahm, 2017).

7.2 Regional Stratigraphy

The Cenozoic basin-fill deposits of the Wind River Basin are chiefly flood-plain and stream channel materials, with generally greater amounts of lacustrine and pyroclastic sediments toward the top of the sequence. The Eocene formations generally consist of lenticular, poorly sorted sediments, whereas the younger Tertiary formations are commonly better sorted and less lenticular in nature. The majority of the volcanic debris was derived from the Yellowstone-Absaroka volcanic field in northwestern Wyoming and to a much lesser extent from the Rattlesnake Hills volcanic field immediately east of the Gas Hills (Van Houten, 1964). The sedimentary strata dip gently a few degrees to the south.

The deposits exposed in the Gas Hills are, from oldest to youngest, the Wind River Formation, Wagon Bed Formation, White River Formation, and the Split Rock Formation. The Wind River Formation can be subdivided into three members that coarsen upwards. The lower fine-grained member is comprised of siltstone, sandstone, and claystone interbeds. The central carbonaceous zone is a 5-15 foot thick sequence

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of carbonaceous shales and thin coal beds. Above the central carbonaceous zone is the Puddle Springs Arkose Member which contains the economic uranium deposits in the Gas Hills District. The Puddle Springs Arkose Member is a coarse- to very-coarse conglomeratic arkose and arkosic sandstone ranging from approximately 400-800 feet thick. The Granite Mountains to the south are the primary source material for the Wind River Formation at the Gas Hills (Gregory, 2019). Depositional processes were influenced by the Eocene climate, which was mostly humid, warm-temperate to sub-tropical in nature (Seeland, 1978). The younger basin-fill sediments (Wagon Bed, White River, Split Rock) are increasingly finer-grained than those arkosic sands of the Wind River Formation, in addition to having substantially more volcanic detritus (Beahm, 2017). Figure 7.1 is a geologic map of the Gas Hills district and Figure 7.2 presents geologic cross sections across the district (Strathmore, 2013). The permit boundary shown on Figure 7.1 depicts the area Strathmore included in their Permit to Mine application and is not the current property outlines which are depicted in Figure 4.1.

7.3 Local Geologic Setting of the Gas Hills

In the Gas Hills district, lower Tertiary rocks unconformably overlie folded and faulted Mesozoic and older rocks (Figure 7.3). The Wind River Formation is conformably overlain by tuffaceous sandstones of the Eocene Wagon Bed Formation.

The Puddle Springs Arkose member of the Wind River Formation is the host rock for the uranium deposits at the Project. It consists of poorly consolidated arkosic sandstone and conglomerate with thin discontinuous interbeds of mudstone. The Puddle Springs arkose was deposited rapidly by northward-flowing braided streams to form coalescing piedmont alluvial fans (Soister, 1968).

The full thickness of the Wind River Formation is present from just north of the base of Beaver Rim Divide southward for a few miles. North of the contact between Wind River Formation and younger rocks, erosion has cut across the formation at a low angle and it progressively thins toward the north, where basal beds lie unconformably on older rocks.

The pre-Cenozoic strata in the Gas Hills are from Cambrian to Cretaceous in age. The Wind River Formation is the predominant rock outcrop at the Project, but Mesozoic and Tertiary formations also outcrop at the surface (Strathmore, 2013). The pre-Cenozoic rocks were extensively deformed during the Early Eocene faulting, uplift and basin development associated with the Laramide Orogeny. The pre-Cenozoic rocks are exposed sporadically throughout the Gas Hills. The area of greatest exposure is along the flanks of the Dutton Basin anticline. The anticline is exposed at the surface one mile east of the George-Ver Property; deposits from the Cody Shale downward to the Chugwater Formation outcrop (Beahm, 2017).

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Figure 7.1. Gas Hills Uranium District Geologic Map

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Figure 7.2. Gas Hills Area Cross Sections

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Figure 7.3. Representative Stratigraphic Column

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7.4 Local Mineralization in the Gas Hills

The uranium deposits are present in an arkosic sandstone facies of the Puddle Springs member of the Wind River formation (Strathmore, 2013). Drilling in the west Gas Hills indicates that the favorable arkosic sandstone grades into an unfavorable silty facies. A local sandstone facies has been found within the silty facies, and a small area containing uranium (Jeep deposit) has been found in the sandstone facies. Thus, the favorable host for mineralization in the above-mentioned deposits is bounded on the north by an erosional pinch out; on the east by a change of facies to an unfavorable silty sandstone host; on the south by a subsurface onlap pinch out; and on the west by change of facies to an unfavorable silty sandstone host.

Uranium mineralization in the Gas Hills is present in bodies usually referred to as “rolls” (King and Austin, 1966; Armstrong, 1970). In vertical cross section they are irregularly crescent or “C” shaped (Figures 7.4 and 7.5). Rolls are the result of oxidized and soluble uranium being transported by ground water to a location within a permeable sandstone host where a reaction within a reducing environment occurs and insoluble reduced, uranium minerals are deposited. The contact between oxidized and reduced conditions is the “roll front”.

Figure 7.4. Typical Uranium Roll-Front System

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Figure 7.5. Roll Front Exposed in Reclamation Channel, George-Ver Deposit

This photograph shows classic Wyoming-type uranium roll-fronts exposed during construction of a

reclamation channel on the Central Unit.

In the body of the crescent, individual rolls range from a few inches to many feet in vertical thickness. Average thickness of a well mineralized roll is 10 to 15 feet; many rolls thicker than 20 feet have been mined. The upper and lower tails of the crescent thin away from the body of the crescent. In the Gas Hills the lower tail normally is greatly extended and thins gradually, whereas the upper tail is typically short and thins abruptly.

On the concave side of a crescent-shaped mineralized body, relatively light gray colored altered host rock is present. The contact is a slightly irregular narrow zone, and the change from uranium-bearing to bleached or altered rock normally takes place within a short distance. On the convex side of a crescent shape mineralized body, relatively dark greenish-gray unbleached (unaltered) rock is present. The contact between uranium-bearing and unbleached or unaltered rock is irregular interfingering, mostly gradational feature but the contact between individual fingers of mineralized rock and unbleached host may be moderately sharp. The fingers of mineralized rock point in the direction of unbleached rock.

Upper-limb mineralization dies out away from the body of the crescent in an abrupt manner somewhat similar to that of the contact between uranium-bearing and bleached rock on the concave side of the crescent. In contrast, lower limb mineralization

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normally terminates gradually in the way that mineralization terminates on the convex side of a roll.

The crescent-shaped contact between bleached rock and uranium mineralization is commonly referred to as a “front”. In mapping a front, the point of maximum advance of the altered rock is indicated. In plan-view, the trace of a front is extremely sinuous.

Rolls may be stacked en echelon, forming multiple mineralized bodies as shown in Figure 7.6. A series of stacked rolls can be thought of as a frontal system. The number of rolls and vertical separation between them can be large or small, and as a result, mineralization may occur through a large stratigraphic interval. In the Central Gas Hills, uranium mineralization has been found in a stratigraphic interval almost 300 feet thick. Most rolls are stacked so that each successively higher roll is displaced in the direction of convexity and the volume of bleached rock narrows with depth. Each roll in a stack has its own front and each front in plan-view has its own sinuosity. The different fronts occur in the same general area, but the detailed sinuosity of one roll is independent of the sinuosity of other rolls.

Rolls and lower-limb mineralized bodies normally are underlain by a mudstone layer. In many places a mudstone layer also overlies the roll. The upper limbs of some mineralized bodies end in sandstone and the next higher roll rests on a mudstone layer that is separated from the lower roll by un-mineralized sandstone.

Un-oxidized mineralization is dark and usually the darker, the higher the grade. The uranium minerals are very fine grained uraninite and a little coffinite. The only non-silicate gangue minerals present in significant amounts are fine-grained pyrite and marcasite, and they are intimately mixed with uranium minerals. These minerals coat detrital sand grains and fill interstices of the host rock. Oxidized mineralization is present near surface and was mined when production in the district first started. Most production came from un-oxidized mineralization and essentially all present mineralization of potential economic interest is contained in un-oxidized mineralization.

Uranium is not distributed uniformly throughout the roll; rather, it is normally concentrated in the body of the crescent close to the concave side. High-grade mineralization locally contains several percent U₃O₈. The grade progressively decreases away from the high-grade zone. In the direction of bleached rock, the grade decreases abruptly and there is a sharp break between mineralization and waste rock. In the direction of unbleached rock, grade decreases gradually. The high- grade zone in the body of the crescent and the area immediately adjacent to it contains most of the total uranium in the body. Most of the uranium produced from the Gas Hills has come from this location in rolls, and therefore most future production can logically be expected to come from similar positions in other rolls.

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Figure 7.6. Depiction of Multiple Stacked, En Echelon Uranium Deposits

(Energy Fuels, 1979)

Uranium was discovered in the Gas Hills near the center of the district at the north end of what later became known as the Central Gas Hills. As exploration continued, uranium was found at widely scattered localities and after a while it became evident that uranium occurrences were concentrated in three separate areas: the western, central and eastern trends. Each trend was considered to be a separate entity until about 1963, when it was realized that the different trends appear to be parts of a single complex, geologic feature (Armstrong, 1970).

In the Gas Hills, the lateral extent of the host sandstone and favorable environment for uranium mineralization is continuous on the order of miles along trend (direction of solution flow in channels) and hundreds of feet across trend. Refer to Figure 7.7 for an illustration in plan-view (EFR, 1979).

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Figure 7.7. Gas Hills Uranium District

Map View of Connected Roll-Front Trends (Energy Fuels, 1979)

Note: The distance between the vertical grid lines (Range Lines) is 6 miles.

7.5 Hydrogeology

The primary groundwater aquifer and the ore-bearing formation in the Project area is the Wind River Aquifer. The general direction of groundwater flow in the Project area is to the north or northwest, with local deviation resulting from faulting and geologic structure. The Wind River Formation is made up of south dipping sand and clay layers with the more transmissive intervals of the Wind River Aquifer found within the upper member of this formation in medium to coarse sands. Within the areas of past mining and the resource areas in the Project area, the Wind River Formation functions as a single aquifer.

The Beaver Rim (or Beaver Divide) and the associated geologic structure profoundly impact the regional groundwater recharge and discharge in the Gas Hills area. Faulting and a series of anticlines north of Beaver Rim create barriers and partial divides within the groundwater basin. The majority of groundwater recharge to the Wind River Aquifer results from snowmelt southeast of and above Beaver Rim. Local recharge below and to the north of the Beaver Rim is limited by the low annual precipitation. The Wind River Aquifer generally discharges to springs or to local alluvial systems associated with major surface drainages north of Beaver Rim. The underlying Cody Shale has a very low

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transmissivity, and because the Wind River Formation pinches out north of the area of the mining units, the groundwater conveyance capacity gradually diminishes to the north of the Project area until the formation is no longer is present.

Groundwater quality and water level data have been monitored for more than three decades by Pathfinder and others. Strathmore initiated a monitoring program in 2007 which was operated through 2011 in preparation for its 2013 mine permit application. The groundwater quality of the Wind River Aquifer is usually hard with sulfate, calcium, sodium, and bicarbonate being the most prevalent major ions.

The potentiometric surface in the Project area has been significantly impacted by past mining and reclamation activities. Pit dewatering and drainage diversions during mining have the potential to profoundly affect the potentiometric surface. The construction of reclamation reservoirs and permanent reclamation diversions also affects the hydrologic system. These activities have been ongoing for more than four decades in the Gas Hills Uranium Project area. Project water-level elevation contouring (Hydro-Engineering, 2018) was developed from data collected for Strathmore’s 2013 mine permit application, though it also includes measurements taken by others primarily for the WDEQ-AML up to the time the contours were created. Water-level elevation south and east of the site is also measured in wells installed by Cameco Resources as part of planned ISR operations. These wells generally reflect the potentiometric surface for the Wind River Aquifer between the historic Central Gas Hills area and Beaver Rim. There has been and still is a general trend showing recovery of the water table throughout the area since mining ended in the 1980s; though this is variable through the Project, with the largest recovery in the southernmost portion of the West Unit nearest to the Beaver Rim at a rate of about 1 foot per year.

The aquifer properties were characterized by Hydro-Engineering (2013, 2018) based on data collected from aquifer pump tests. Results from single and multi-well pump tests conducted by Pathfinder in the late 1970’s and early 1990’s were compiled by Hydro-Engineering with pump tests performed by Strathmore in 2008.

In 2021, Hydro-Engineering developed a MODFLOW-2005 numerical groundwater flow model within the major proposed ISR resource areas within the Central Unit. The modeling objective was to evaluate the magnitude and extent of predicted drawdown that would occur within in the potential ISR mining area and utilized data previously assembled by Hydro-Engineering from previous studies of the Project as detailed above. Results of the model indicated that for a life-of-mine production scenario ISR operations could be sustained, with a suitable but minor depression of the water table within the ISR pattern area and with the majority of water column above the immediate mining zone intact during ISR extraction. The analysis included stresses based on ISR wellfield design parameters designed to achieve approximately 1 million pounds U₃O₈ per year production. The simulation included a constant withdrawal from the aquifer during ISR operations at an operational bleed rate of 1 percent, which is the resulting difference between slightly greater overall production flowrate than overall injection flowrates that creates a constant inward flow necessary for controlling ISR mining solutions.

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The general surface water conditions include numerous ephemeral drainage channels with significant alteration of local drainages by past mining activity. Perennial surface water bodies in the Project area have resulted from reclamation of mine pits to create several reservoirs, and from blockage of natural drainages fed by springs. There are limited reaches of perennial streams fed by natural springs, but the majority of natural and reclamation drainage channels are highly ephemeral with relatively infrequent flow.

It is the opinion of the Authors that previous hydrogeologic studies were generally conducted using industry-standard practices and procedures meeting regulatory requirements and place at the time the work was conducted.

7.6 Geotechnical Testing

Geotechnical investigations will be conducted at the Project prior to the construction of the CPP and associated infrastructure.

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8.0 DEPOSIT TYPES

Uranium deposits in the Gas Hills were formed by the classic Wyoming-type roll-fronts. Roll-fronts are irregular in shape, roughly tabular and elongated, and range from thin pods and a few feet in width and length, to bodies several hundred or thousands of feet in length. The deposits are roughly parallel to the enclosing beds but may form rolls that cut across bedding. Roll-front deposits are typified by a C-shaped morphology in which the outside of the C extends down-gradient in the direction of historic groundwater flow and the tails extend up-gradient of historic groundwater flow. As shown in Figure 8.1, tails are typically caught up in the finer sand and silt deposits that grade into over and underlying mudstones, whereas the heart of the roll-front (higher grade mineralization) lies within the more porous and permeable sandstones toward the middle of the fluvial deposits

Figure 8.1. Idealized Cross-Section of a Sandstone-Hosted Roll Front Uranium Deposit

Modified from Granger and Warren (1974) and De Voto (1978).

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9.0 EXPLORATION

Since acquiring the Project, enCore performed no exploration other than drilling one core hole in the West Unit during 2024.

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10.0 DRILLING

10.1 Drilling Methods

Available drill data consists of radiometric equivalent data (eU₃O₈) for 4,570 drill holes (4,056 pre-2007), eU₃O₈ data and PFN assay data for 272 drill holes completed from 2007 to 2013, and eU₃O₈ data and core data from one core hole completed in the West Unit by enCore in 2024. Drilling from 2007 to 2024 consisted of monitoring wells and exploration holes. Some pre-2007 drill holes were also re-drilled or washed-out for comparison of results to newer logging tools by previous operators as discussed in Section 11.0. Table 10.1 summarizes the drilling and geophysical data available for this resource estimate. Average depth of drilling for the entire Project is approximately 330 ft and ranges in depth from approximately 80 ft to 1,280 ft.

Table 10.1.  Drilling Summary by Area

Area		Pre-2007    Drill Holes		2007-2024    Drill Holes		PFN logged    Drill Holes		Core Collected  Drill Holes
Central Unit		1204		195		75		14
West Unit		1956		202		146		13
Jeep		296		40		0		0
South Black Mountain		41		20		3		0
Rock Hill		41		57		48		4
Total		4056		514		272		31

The vast majority of the drilling (pre and post 2007) was conducted by air and/or mud rotary drilling (vertical) with limited core drilling for evaluation of radiometric equilibrium conditions. The principal data collected for mineral resource estimation by drilling was downhole radiometric equivalent assays. Geologic data collected included lithologic descriptions of drill cuttings and interpretation of geophysical logs (Spontaneous Potential and Resistivity).

Similar lithological and downhole radiometric equivalent assay data were collected during the 2011 and 2012 drilling campaigns. Downhole prompt fission neutron (PFN) geophysical logs were also completed on some holes to provide an in-situ uranium assay for comparison to the radiometric equivalent data.

As no current drilling was being undertaken at the time of the May 24, 2021 site visit, no physical check of work practices was possible. After review of available documentation and discussions with enCore site personnel, the Authors conclude that the previous drilling procedures were consistent with industry standard practice and acceptable for use in resource estimation.

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10.2 Drilling Length Versus True Thickness

Downhole drift surveys are available only for the 2011 and 2012 drilling. These surveys show random deviation from vertical of 1 to 3^o. No deviation of the drill holes was assumed in the mineral resource estimation and this is considered reasonable as explained in following.

The dip of the Wind River Formation within the Project varies from 2 to 6^o. If the combination of dip and downhole deviation resulted in an effective deviation of 5^o from vertical, the true thickness of mineralization would vary by approximately 0.4 percent, i.e., a 10-foot apparent thickness would equate to a true thickness of 9.96 feet. The Authors concludes that this possible variation is well within the accuracy of the resource estimate.

Core recovery is not an issue as uranium grade is determined primarily by geophysical methods in an open drill hole.

10.3 Summary and Interpretation of Relevant Drill Results

Drill hole locations are shown on maps in Section 14.0. The Authors have reviewed the available drill data and considers the information suitable for the purposes of this Report. See Section 12.0 for details on drill data verification.

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11.0 SAMPLE PREPARATION, ANALYSES AND SECURITY

11.1 Radiometric Equivalent Geophysical Log Calibration

The US DOE supports the development, standardization, and maintenance of calibration facilities for environmental radiation sensors. Radiation standards at the facilities are primarily used to calibrate portable surface gamma-ray survey meters and borehole logging instruments used for uranium and other mineral exploration and remedial action measurements. This is an important quality control measure used by the geophysical logging equipment operators. The Authors have reviewed the geophysical logs and they have annotation of the calibration parameters necessary for the accurate conversion of gamma measurements recorded by the logging units to radiometric equivalent uranium grade. enCore has acquired exploration files for the Project which includes original geophysical logs and data. This data is securely stored at their facility in Edgemont, South Dakota and on offsite cloud-based servers.

Calibration facilities are located at the US DOE sites at Grand Junction Regional Airport in Grand Junction, Colorado; Grants, New Mexico; Casper, Wyoming; and George West, Texas (https://energy.gov/lm/services/calibration-facilities). These calibration facilities were first established by the AEC in the 1950’s to support the domestic uranium exploration and development programs of that era.

Early geophysical logs were analog which required manual interpretation. The standard method for estimation of the grade and thickness of uranium was the half-amplitude method. In the late 1960’s this method was gradually replaced with computer processing. Dodd et al. (1967) state that borehole logging is the geophysical method most extensively used in the US for the exploration and evaluation of uranium deposits and that gamma-ray logging at that time supplied 80 percent of the basic data for ore reserve calculations and much of the subsurface geologic information. At that time calibration and correction factors were established for each logging unit and probe in the full-scale model holes established by the AEC. GAMLOG and RHOLOG computer programs (Fortran II) were used to quantitatively analyze gamma-ray logs to obtain radiometric equivalent grade and thickness of mineralized intercepts (Dodd et al., 1967).

In 1942 Century Geophysical Corporation, now Century Wireline Services (Century) began research and development of geophysical logging techniques in the US and introduced analog geophysical logging equipment for the uranium industry by 1960. In the late 1970’s Century pioneered digital logging and continues to provide these services (Century, 2017). Century’s geophysical logging equipment is and has been calibrated at US facilities operated by the AEC, its successor the Energy Research and Development Administration (ERDA), and the successor to AEC and ERDA, the US DOE. Tools used for uranium logging are calibrated and assigned dead times and K-factor values at government provided uranium calibration pits. At the same time Century logs field calibration test sleeves which may then be used for daily tool calibration checks

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to verify that K-factor and dead times have not changed (Century, 2017 and Century, 1975).

Calibration procedures and standards for the geophysical logging equipment used in the determination of radiometric equivalent uranium grade has been consistent through the various drilling campaigns and has relied on calibration facilities maintained by the US government. It is standard practice for Century and other geophysical logging companies to rely on these calibration facilities. Century calibrates to the primary standards located at ERDA facilities in Grand Junction, Colorado where a family of calibration models are maintained. These models consist of a barren zone bored in concrete and a mineralized zone constructed of a homogenous concentration of uranium at a known grade followed by and underlying barren zone. There are different grade models to reflect the range on uranium concentrations typically found in the US. In addition, the models can be flooded to determine a water factor and there are models which are cased for the determination of a casing factor. Each of the models are approximately 9 feet deep consisting of a 3-foot mineralized zone with 3-foot barren zones above and below. The facilities are secure. Logging unit operators logs the holes, provide the geophysical log data in counts per second (CPS) to the facility which in turn processes the data and provides the company with standard calibration values including, dead time, K Factor, and water and casing factors (Century, 1975).

11.2 Pre-2007 Drilling Analyses

Pre-2007 drillhole logging in the Gas Hills was done by the mining and exploration companies themselves, using their own equipment and was also performed by Century Geophysical, Scinti-Log, Frontier Logging, Rocky Mountain Logging, and Geoscience Associates. These independent geophysical logging companies are and/or were well-known, well respected, and considered to have operated well within industry standards of the time. It was then, and still is standard industry practice to routinely calibrate downhole geophysical logging equipment at the facilities operated by the US DOE.

Standard electric logs consisted of recordings of gamma, self-potential, and resistivity. Self-potential and resistivity data are useful in defining bedding boundaries and for correlation of sandstone units and mineralized zones between drill holes. At the time of the pre-2007 drilling, equivalent U₃O₈ content was calculated from gamma logs using industry-standard methods developed by the AEC (now the US DOE), using either manual or computer methods. The manual method is as follows:

For zones greater than 2 feet thick, first pick an upper and lower boundary of mineralization by choosing points approximately one-half height from background to peak of gamma anomaly. Then determine cps for each half-foot interval between the points, convert cps to GT (grade times thickness) using the appropriate dead-time, k-factor and water factor for the specific logging unit utilized, and divide GT by thickness to obtain grade % eU₃O₈.

These gamma log interpretations are the basis from which quantities of mineralization could be calculated. These interpretations were industry standard at the time (1950s

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through 1980s) and, in the case of the Gas Hills Uranium Project, validated by more recent drilling and logging, and therefore considered appropriate for use in the mineral resource estimates reported in Section 14.0.

The AEC published information the calibration standards for geophysical logging and on gamma log interpretation methods (Dodd et al., 1967). The standard manual log interpretation method was the half-amplitude method (Century, 1975). The AEC and its successor agency conducted workshops on gamma-ray logging techniques and interpretation as did private companies including Century Geophysical.

11.3 Post-2007 Drilling

Starting in 2007, Strathmore implemented a program of exploration and confirmation drilling utilizing standard gamma logging, and from 2011 to 2013, both PFN and gamma logging. This program served as a check on the pre-2007 drilling results in that it confirmed the grade and thickness of uranium for those holes drilled and allowed comparison of results to nearby or adjacent holes from pre-2007 drilling. In 2011, limited reverse circulation drilling was completed to provide bulk material for metallurgical testing. In 2012, Strathmore implemented core drilling at the Bullrush, Day Loma, George-Ver, Loco-Lee and Rock Hill properties for chemical assay determinations to compare the results of their gamma and PFN logging, see Table 10.1 for a summary of core holes completed.

Drill core was typically split and sampled in half-foot or one-foot intervals and sent to various laboratories for uranium analysis. These analyses typically included: fluorometric chemical analysis and closed-can radiometric analysis.

Core assays (2011/2012) were performed by either Chemical and Geological Laboratories of Casper, Wyoming or Skyline Laboratories of Wheat Ridge, Colorado. Both laboratories were independent commercial laboratories. Specific core handling procedures and laboratory certifications for historic analyses are not known.

The PFN is a specialized logging tool with neutron activation to determine the uranium concentrations in drilled holes. The PFN logging utilizes two different tools used one after the other; a standard gamma tool followed by the PFN tool. Disequilibrium was evaluated by using direct comparisons of uranium grades determined PFN and radiometric equivalent uranium grades gamma logs.

The PFN tool creates neutron-induced fission reactions with U²³⁵ atoms present in the host rocks. The U²³⁵ atoms emit delayed neutrons which reactivate and are counted by the probe’s detector. This delay cycle is repeated a number of times to accumulate a statistically acceptable number of delayed neutron counts. If uranium is present, the “decay” times of the delayed neutrons is proportional to the uranium content and is independent of disequilibrium or changes in density. This method can be used to determine the direct content of uranium in the host rocks.

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Beginning in May 2012, third-party independent PFN and gamma logging provided by GAA Wireline Inc. of Casper, Wyoming was also employed. GAA operated their own logging equipment and at times provided loggers who operated Strathmore’s company-owned PFN logging truck. GAA provided calibration documentation of test pit runs, which were reviewed.

11.4 Security

For 2011 and 2012 drilling security practices involved: awareness of chain-of-custody issues, limited access to logging tools through locked storage as approved by the US Nuclear Regulatory Commission, and continuing calibration of logging tools to assure that no tampering has occurred. All drill hole samples were in locked storage until sent out for laboratory testing. Drill cutting samples were generally not preserved and it was typical for the mine operators to assay drill samples at their on-site laboratories.

11.5 Summary

The Authors reviewed the available drill data and independently correlated mineralized horizons and reviewed appropriate composite intervals for use in mineral resource estimation. It is the Authors’ opinion that the available drill data is reliable and adequate for the estimation of measured, indicated and inferred mineral resources.

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12.0 DATA VERIFICATION

Data sources reviewed for the estimation of uranium mineral resources for the Project include radiometric equivalent data (eU₃O₈) for 4,570 drill holes (4,056 pre-2007), eU₃O₈ data and PFN assay data for 272 drill holes completed from 2007 to 2013, and eU₃O₈ and core data for one core hole completed in 2024. For the 2011-2012 drilling programs, downhole geophysical logging using the PFN tool was completed with Strathmore’s PFN logging truck and independently confirmed by GAA Wireline Services.

Extensive verification work was previously completed for holes drilled pre-2007 in the 2017 mineral estimate (Beahm, 2017). This Report used the results of the 2007 to 2013 drilling as part of the verification procedures on the pre-2007 drilling. The Authors reviewed this analysis as well as post-2007 drilling raw data.

12.1 Verification of Radiometric Database

The pre-2007 drill data was originally collected by several operators including American Nuclear Corporation (ANC), Federal American Partners (FAP), Pathfinder Mines/Areva (PMC), Western Nuclear (WNC), Energy Fuels (EFR), Union Carbide Corporation (UCC), Adobe-Vinpoint (Adobe), Power Resources Inc. (PRI), and others. These companies either utilized their own geophysical logging equipment, commercial logging services, or a combination of the two. The pre-2007 drill data includes geophysical logs from Century Geophysical, Scinti-Log, Rocky Mountain Logging, Frontier Logging Services, and Geoscience Associates. It was standard industry practice at the time, and it is the current practice, to maintain calibration of geophysical logging equipment through use of the AEC/ERDA (now the US DOE) standard calibration pits located at Casper, Wyoming and Grand Junction, Colorado for quality control and assurance with respect to radiometric equivalent data.

Electronic copies of geophysical logs are in possession of enCore and were reviewed by the Authors. The pre-2007 drill logs contain header information for essentially all of the drill holes including K Factor, Dead Time, and Water Factor. Several of the drill holes headers also included notes as to the date of calibration of the logging unit at the ERDA test pits. Pre-2007 drill data generally consists of geophysical logs of drill holes including of copies of original drill logs and copies of digital printouts of depth and cps in ¹⁄₂ foot increments within the mineralized zones. The geophysical logs include natural gamma, resistivity, and spontaneous potential (SP). All drill holes were drilled with fluid and logged in the open hole with no casing. All drill holes were vertical with no drift data.

Radiometric equivalent data is available for essentially all the pre-2007 holes and is incorporated into the drill hole database.

The post-2007 drill data, both electronic and hard copy, includes, original geophysical log prints and digital Log Assay Standard (LAS) files, hard copy printouts and digital ¹⁄₂ foot radiometric equivalent data, gamma calibration data files from the US DOE test pits, and hard copy and scans of field lithologic logs. The same type and form of data

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is available for drill holes logged with the PFN logging unit. Core data includes chain of custody and laboratory certificates.

Beahm reviewed 46 PFN logs which have both radiometric equivalent data and PFN uranium assay data, checked this data against the electronic database, and prepared the correlations of this data for evaluation of disequilibrium.

The pre-2007 drill data was combined with data from 2007-2013 drilling in an electronic database. During the preparation of this Report, the available electronic data was reviewed for each of the mineral resource areas. This process included:

• Plotting of the drill hole locations and comparing these to drill maps prepared by previous operators.

• Screening the drill hole data and preparing a subset of the data containing mineralized intercepts meeting grade, thickness and GT cutoff criteria.

• Correlating the mineralized intercept data such that mineral resource estimates reflected only continuous horizons.

• Excluding any spurious mineralized horizons (laterally or by depth from the continuous horizons) from the mineral resource estimate.

• Examining any mineralized intercepts which were either substantially higher or lower than the surrounding values to ensure the data was considered reliable and therefore suitable to be used.

• Confirmation of vertical correlation between mineralized zones of pre-2007 and 2007-2013 data.

All intercept data from the electronic database and GT-contours initially generated by Azarga were reviewed in CAD software by WWC for auditing purposes. WWC was able to verify the mapped resource contours as well as compare and verify the internal consistency of the electronic database.

12.2 Verification of Disequilibrium Factor

Radioactive isotopes decay until they reach a stable non-radioactive state. The radioactive decay chain isotopes are referred to as daughters. When all the decay products are maintained in close association with the primary uranium isotope U²³⁸ for the order of a million years or more, the daughter isotopes will be in equilibrium with the parent isotope (McKay et al., 2007). Disequilibrium occurs when one or more decay products are dispersed as a result of differences in solubility between uranium and its daughters.

Disequilibrium is considered positive when there is a higher proportion of uranium present compared to daughters and negative where daughters are accumulated, and

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uranium is depleted. The disequilibrium factor (DEF) is determined by comparing radiometric equivalent uranium grade eU₃O₈ to chemically measured uranium grade. Radiometric equilibrium is represented by a DEF of 1, positive radiometric equilibrium by a factor greater than 1, and negative radiometric equilibrium by a factor of less than 1.

Except in cases where uranium mineralization is exposed to strongly oxidized conditions, most of the sandstone roll front deposits reasonably approximate radiometric equilibrium. The nose of a roll front deposit tends to have the most positive DEF and the tails of a roll front would tend to have the lowest DEF (Davis, 1969).

Radiometric versus chemical data are available throughout the Project. Extensive data, analysis, and discussion of the comparability of PFN data with chemical assays from core was previously completed which concluded the PFN assays were reliable (CAM, 2013). Beahm reviewed this information, completed independent calculations, and found the CAM conclusions to be reasonable and appropriate. Overall, the calculated DEF was positive averaging 1.2:1 which means the actual grade of uranium mineralization is higher than the radiometric equivalent grade. The DEF was found by Beahm to vary by area, ranging from 0.80:1 to 1.5:1 (Beahm, 2017).

Although available data indicates an overall positive DEF, a DEF of 1 is applied in this estimate and no correction to the radiometric equivalent data relative to % eU₃O₈ is used in this estimate_. The Authors have reviewed the previous DEF analysis and deems this to approach to be a conservative, since a positive correction would result in an overall higher % eU₃O₈ values and an overall higher quantity resource estimate. The Authors also find this approach to be consistent with typical industry practice for uranium ISR projects.

12.3 Verification of Pre-2007 Drilling by Re-Logging

In 2011 and 2012 some pre-2007 drill holes were re-entered and re-probed using modern gamma and PFN logging tools. Where available, the pre-2007 gamma logs were scanned and displayed adjacent to the modern gamma/PFN logs. These holes compare favorably with respect to depth, thickness, grade and GT.

12.4 Density of Mineralized Material

The density of mineralization used in the Gas Hills for resource estimation was 16 cubic feet per ton. This is the most common figure used for sandstone hosted, roll-front uranium deposits in Wyoming and Colorado, as noted extensively throughout the literature on these deposits. Density studies were completed on core retrieved in March and December 2012. The studies were completed by Intermountain Labs of Sheridan, Wyoming and DOWL-HKM of Lander, Wyoming, respectively. The overall average of the 26 samples was 16.49 ft³/ton.

Based on the limited number of core sampled for density, and the overall average being very similar to the 16 ft³/ton average used historically, this Report has assumed a

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density factor of 16 ft³/ton for the mineral resource estimates reported in Section 14.0. The Authors find this value to be representative and also slightly conservative.

12.5 Summary

Based on the outcomes of the above data verification, the Authors consider the Project data sufficiently reliable for mineral resource estimation and related work. No deficiencies were found in the verification and audit of this information.

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13.0 MINERAL PROCESSING AND METALLURGICAL TESTING

Ore from past mining within the Gas Hills was processed using conventional milling, recovery, and extraction methods including the Union Carbide, Pathfinder, and Federal American Partners mills located in the Gas Hills. Ore from the Gas Hills was also shipped to the Susquehanna mill in Riverton, Wyoming and the Western Nuclear mill near Jeffery City, Wyoming (Snow, 1978). Heap leach recovery operations were also successfully conducted by Union Carbide at their East Gas Hills facility (Woolery et al., 1978) and at the West Unit by Western Nuclear Corporation.

One of the previous operators, Strathmore, conducted preliminary metallurgical testing in 2011 on bulk samples collected from reverse circulation drill holes. The results are consistent those experienced when the mines were in production (Beahm, 2017).

In May 2011, Strathmore commissioned Lyntek Inc. of Lakewood, Colorado, an experienced firm in uranium engineering and processing research, to carry out preliminary metallurgical studies and investigate the proposed Gas Hills uranium heap leach recovery plans. These studies included bottle-roll testing, three separate column leach studies, and testing of Ion Exchange Resin (Lyntek, 2013, Lyntek and Alexander, 2013).

13.1 Uranium Extraction Bottle Roll Testing

Lyntek completed 11 total bottle roll tests using core ranging in mineral grade from 0.069% - 0.258% U. Using all of the metallurgical tests to evaluate recovery showed that recoveries ranged between 55.8 percent and 97.9 percent and typically had acid consumptions ranging from 8.6 to 230 pounds per ton. The average recovery of all eleven leach tests was 90.0 percent with an average acid consumption of 55.4 pounds per ton. The individual bottle roll tests consisted of each of the following: 2 cores from the West Unit, 4 cores and 1 duplicate from the Central Unit, 2 cores from Rock Hill, and 1 blended core sample and 1 blended core sample duplicate.

13.2 Uranium Extraction Column Testing

Lyntek completed two initial column leach tests with two blended samples from cores collected from the West Unit, Central Unit, and Rock Hill configured to be a high-grade composite with an average grade of 0.135% U and a low-grade composite with an average grade of 0.023% U. Lyntek also conducted a third column leach test using a sample of stockpile ore from the Central Unit with an average grade of 0.137% U that was highly oxidized due to prolonged exposure to the atmosphere. Though the tests were all run well past reaching an asymptotic recovery point, all three results appear to confirm a suitable target of 90 percent recovery. Results of the initial two blended core samples showed what was deemed a “quick” extraction with maximum recovery of 98.4 percent reached in approximately 21 days in the high-grade sample and a maximum recovery of 98.9 percent recovery of the low-grade sample in approximately 9 days. In the third test, 90 percent recovery was reached in approximately 65 days.

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13.3 IX Testing

Preliminary ion exchange extraction tests showed that uranium could be successfully loaded by this method and that Dowex 21K resin was a favorable resin choice for use in processing recovery solutions from the site.

13.4 Summary

In summary, while the history of uranium production in the Gas Hills demonstrates that uranium is recoverable from mineralized material and recent metallurgical testing indicates favorable results, Lyntek recommended additional metallurgical testing be conducted. Specifically, Lyntek recommended that metallurgical studies to further expand the understanding of the range of metallurgical conditions and process variables that may be incorporated into mine plans, and which further simulate the proposed mineral processing method, be performed. This includes both heap leach and ISR extraction scenarios.

The Authors have reviewed the studies by Lyntek and finds them to be supportive that both assumed mining methods of this Mineral Resource estimate have reasonable prospects for economic extraction.

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14.0 MINERAL RESOURCE ESTIMATES

14.1 Mineral Resource Definitions

A technical review and resource estimation was completed by WWC for this resource update using CAD software. Mineral resources reported in this Report are classified as Measured, Indicated, and Inferred. Classification of the resources reflects the relative confidence of the grade estimates. Mineral resources that are not mineral reserves do not have demonstrated economic viability. There is no certainty that all or any part of the mineral resource will be converted into mineral reserve. The effective date of the Mineral Resource estimate is December 31, 2024.

This section describes the resource estimation methodology and summarizes key assumptions considered by the Authors. In the opinion of the Authors, the resource evaluation is a reasonable representation of the uranium resources found in the Gas Hills.

The database, GT-contours, and calculations used to estimate the Gas Hills Uranium Project mineral resources were audited by WWC and it is the opinion of the Authors that the current drilling information is sufficiently reliable to interpret the extents of the pods and the assay data are sufficiently reliable to support mineral resource estimation.

14.2 Basis of Mineral Resource Estimates

14.2.1 Methodology

The mineral resource estimates are based on radiometric equivalent uranium grades % eU₃O_8. A minimum 0.02% eU₃O₈, minimum 1.0-foot thickness, and minimum GT of 0.10 was used in the estimations along with a bulk dry density of 16 cubic feet per ton. Resources were estimated using the GT contour method, which is industry standard for this type of deposit. The GT was determined for each drillhole by major stratigraphic horizon, then the GT was summed separately for each mineralized sub-horizon for intercepts meeting the cutoff criteria. Contours were drawn in two-dimensional space around horizon intercepts, allowing projection up to 100 feet across a mineralized trend and up to 600 feet along the mineralized trend. The GT contour maps provided in Section 14.5 provide a graphical representation of the mineralization reflecting the location, quality, GT, and continuity of the mineralization.

Average GT for each contour was calculated one of two ways depending on if the contour was the highest GT contour or if it contained another, higher GT contour. If the contour was the highest GT contour, all GT values within the contour were averaged, then averaged with the value of that GT contour. For example, a 1.0 GT contour with two GT values of 1.20 and 1.47 and no higher contour within would be (((1.20+1.47)/2)+1.0)/2 = 1.17 average GT. If the contour contained another higher contour, the average GT was the average of the upper and lower GT contour values.

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For example, a 1.0 GT contour with a 2.0 GT contour within would be (1.0+2.0)/2 = 1.5 average GT.

Pounds of uranium for each contour were calculated by multiplying the contour area by GT for the contour and applying the conversion constant and dividing by bulk density factor ((Area x Avg GT x 20)/16 = Pounds). Tonnage was calculated by multiplying composited contour thickness by contour area to get cubic feet, then converting to tonnage by applying the density factor (Thickness x Area/16).

The 0.10 GT base case cutoff was selected by meeting economic criteria for both ISR and open pit/heap leach methods differentiated on the relative location to the water table. Resources labeled “ISR” meet the criteria of being sufficiently below the water table to be amenable by ISR methods and as well as also meeting other hydrogeological criteria. “Non-ISR” resources include those generally above the natural water table, which would typically be mined using open pit methods.

14.3 Key Assumptions and Parameters

Mineral resources were classified as measured, indicated, and inferred based on the distance to the nearest drilling intercept to measure drilling density. To be classified as measured resources, the contour must fall within 100 feet of a mineralized drill hole intercept in that horizon. Indicated resources must fall between 100 and 250 feet from the nearest mineralized intercept in that horizon. Inferred resources must be within 600 feet of a mineralized intercept in that horizon.

The GT contours were divided and classified based on area contained within each of the distance boundaries from drillhole intercepts. Figure 14.1 shows contours for an example pod within the Central Unit that shows how categories were allocated within each mineralized pod for resource classification with respect to drilling density.

After classifying resources based on distance from drilling, further consideration was given to applicable mining methods for each pod. Reclassification of resource was determined based on local water table levels at each resource pod and the level of detail of hydrogeologic understanding.

At this time, only the Central Unit has had groundwater flow modeling completed. All other ISR resource which met the measured criteria for ISR drilling density were classified as indicated resource until more detailed hydrologic studies to support ISR are conducted on these resource areas.

14.3.1 Cutoff Criteria

The cutoff used for mineral resource classification was a minimum 0.02% eU₃O₈, minimum 1.0-foot thickness, and minimum 0.10 GT. These criteria were determined to meet the criteria for “reasonable prospects for economic extraction” for both ISR and open pit heap/leach mining methods. The GT cutoff of 0.10 GT is also consistent with previous historic resource estimation in the area. The average grade of ISR resources in

Gas Hills Uranium Project Technical Report – February 2025 Page 48

Figure 14.1. Resource Classification Boundaries

this estimate at a 0.10 GT cutoff met economic criteria for ISR extraction, and thus is considered the base case for this Report.

When drawing GT contours, the maximum allowable GT was set at 7.0. Any drilling intercept with a higher GT was included in the 7.0 GT contour and assigned that value.

14.3.2 Bulk Density

The bulk density value of 16 cubic feet per ton was used to calculate the resource estimate. Verification of the use of this value can be found in Section 12.4.

14.3.3 Radiometric Equilibrium

Evaluation of radiometric equilibrium is discussed on Section 12.0 of this Report. While the average disequilibrium factor for the five Project areas was greater than 1 (1.20), the disequilibrium factor varied by area, ranging from 0.80 to 1.50. For the purposes of assessing the overall mineral resources for the Project, it is recommended that no correction for radiometric equilibrium be applied for this level of study. Based on the available data and the geological setting of the mineral deposits, the Authors consider it appropriate to assume a DEF factor of 1 for all mineral resource estimates.

14.4 Mineral Resource Summary

Mineral resources for the Project are estimated by classifications meeting CIM standards and definitions, at a 0.10 GT cutoff, as summarized in Tables 14.1 and 14.2.

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Subsequent Sections 14.4.1 through 14.4.5 provide specific summaries for the West Unit, Central Unit, Rock Hill, South Black Mountain, and Jeep areas, respectively.

Table 14.1.  Measured and Indicated Mineral Resource Summary

December 31, 2024 (GT cutoff 0.10)
		Pounds				Tons				Avg. Grade		Avg. Thickness		Avg. GT
Measured			2,051,000				994,000			0.10%		5.35		0.552
Indicated			8,713,000				6,031,000			0.07%		6.13		0.443
Total M&I			10,764,000				7,025,000			0.08%		6.05		0.463
December 31, 2024, ISR Only (GT cutoff 0.10)
		Pounds				Tons				Avg. Grade		Avg. Thickness		Avg. GT
Measured			2,051,000				994,000			0.10%		5.35		0.552
Indicated			5,654,000				2,835,000			0.10%		4.92		0.491
Total M&I			7,705,000				3,829,000			0.10%		4.99		0.502
December 31, 2024, Non-ISR Only (GT cutoff 0.10)
		Pounds				Tons				Avg. Grade		Avg. Thickness		Avg. GT
Indicated			3,059,000				3,196,000			0.05%		8.6		0.412
Total M&I			3,059,000				3,196,000			0.05%		8.6		0.412

Notes:

1. Mineral resources as defined in 17 CFR § 229.1300 and as used in NI 43-101.

2. All ISR Only resources occur below the static water table.

3. The point of reference for mineral resources is in-situ at the Project.

4. Mineral resources that are not mineral reserves do not have demonstrated economic viability.

5. An 80% metallurgical recovery factor was considered for the purposes of the economic analysis.

6. Totals may not sum due to rounding.

Table 14.2.  Inferred Mineral Resource Summary

December 31, 2024 (GT cutoff 0.10)
		Pounds				Tons				Avg. Grade		Avg. Thickness		Avg. GT
Inferred			490,000				514,000			0.05%		6.16		0.293
December 31, 2024, ISR Only (GT cutoff 0.10)
		Pounds				Tons				Avg. Grade		Avg. Thickness		Avg. GT
Inferred			428,000				409,000			0.05%		5.94		0.31
December 31, 2024, Non-ISR Only (GT cutoff 0.10)
		Pounds				Tons				Avg. Grade		Avg. Thickness		Avg. GT
Inferred			62,000				105,000			0.03%		7.01		0.208

Notes:

1. Mineral resources as defined in 17 CFR § 229.1300 and as used in NI 43-101.

2. All ISR Only resources occur below the static water table.

3. The point of reference for mineral resources is in-situ at the Project.

4. Mineral resources that are not mineral reserves do not have demonstrated economic viability.

5. Totals may not sum due to rounding.

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14.4.1 West Unit

There are a total of 2,157 drill holes in the database for the West Unit. Depth of ISR amenable mineralization varies, ranging in depth from approximately 200 to 630 feet with an average depth of approximately 280 feet below ground surface. Non-ISR resources range in depth from surface to approximately 290 feet in depth with an average depth of approximately 150 feet. Additionally, several pods were identified in the northern portion of the West Unit that were located near a significant fault. Due to uncertainty of the hydrogeologic conditions and the lack of groundwater modeling in proximity to the fault, ISR amenable resources that met measured or indicated contours of drilling density were classified as inferred. Mineral resources for the West Unit are shown in Tables 14.3 and 14.4.

Table 14.3.  West Unit Measured and Indicated Mineral Resource Summary

December 31, 2024 (GT cutoff 0.10)
		Pounds				Tons				Avg. Grade		Avg. Thickness		Avg. GT
Indicated			5,272,000				2,985,000			0.09%		5.75		0.507
Total M&I			5,272,000				2,985,000			0.09%		5.75		0.507
December 31, 2024, ISR Only (GT Cutoff 0.10)
		Pounds				Tons				Avg. Grade		Avg. Thickness		Avg. GT
Indicated			3,712,000				1,547,000			0.12%		4.92		0.591
Total M&I			3,712,000				1,547,000			0.12%		4.92		0.591
December 31, 2024, Non-ISR Only (GT Cutoff 0.10)
		Pounds				Tons				Avg. Grade		Avg. Thickness		Avg. GT
Indicated			1,561,000				1,438,000			0.05%		8.02		0.435
Total M&I			1,561,000				1,438,000			0.05%		8.02		0.435

Notes:

1. Mineral resources as defined in 17 CFR § 229.1300 and as used in NI 43-101.

2. All ISR Only resources occur below the static water table.

3. The point of reference for mineral resources is in-situ at the Project.

4. Mineral resources that are not mineral reserves do not have demonstrated economic viability.

5. An 80% metallurgical recovery factor was considered for the purposes of the economic analysis.

6. Totals may not sum due to rounding.

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Table 14.4.  West Unit Inferred Mineral Resource Summary

December 31, 2024 (GT cutoff 0.10)
		Pounds				Tons				Avg. Grade		Avg. Thickness		Avg. GT
Inferred			301,000				295,000			0.05%		6.87		0.35
December 31, 2024, ISR Only (GT Cutoff 0.10)
		Pounds				Tons				Avg. Grade		Avg. Thickness		Avg. GT
Inferred			293,000				284,000			0.05%		6.76		0.349
December 31, 2024, Non-ISR Only (GT Cutoff 0.10)
		Pounds				Tons				Avg. Grade		Avg. Thickness		Avg. GT
Inferred			8,000				11,200			0.03%		8		0.271

Notes:

1. Mineral resources as defined in 17 CFR § 229.1300 and as used in NI 43-101.

2. All ISR Only resources occur below the static water table.

3. The point of reference for mineral resources is in-situ at the Project.

4. Mineral resources that are not mineral reserves do not have demonstrated economic viability.

14.4.2 Central Unit

The Central Unit contains the George-Ver and Frazier Lamac mine complex located within the Central Gas Hills. These two historic areas were extensively mined in the past predominantly by open pit methods. The majority of the George-Ver and Frazier Lamac areas have been drilled on 100-foot centers or less. ISR amenable resources range in depth from 130 feet to approximately 280 feet and average approximately 210 feet below surface. Non-ISR resources range in depth from surface to approximately 310 feet with an average depth of approximately 110 feet. The depth to ore horizons varies widely based on surface topography. A detailed groundwater model (see Section 7.5) was conducted in the Central Unit specifically on the George Ver/Frazier Lamac deposit to demonstrate that conditions for extraction were suitable to sustain sufficient water levels over a life-of-mine operating scenario (Hydro-Engineering, 2021). Some ISR resources in the George Ver/Frazier Lamac areas are classified as Measured Resource because of the combination of drilling density, high-level hydrologic study, and supporting metallurgical analysis. Mineral resources for the Central Unit are shown in Tables 14.5 and 14.6.

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Table 14.5.  Central Unit Measured and Indicated Mineral Resource Summary

December 31, 2024 (GT Cutoff 0.10)
		Pounds				Tons				Avg. Grade		Avg. Thickness		Avg. GT
Measured			2,051,000				994,000			0.10%		5.35		0.552
Indicated			1,110,000				1,038,000			0.05%		5.86		0.313
Total M&I			3,161,000				2,032,000			0.08%		5.62		0.437
December 31, 2024, ISR Only (GT Cutoff 0.10)
		Pounds				Tons				Avg. Grade		Avg. Thickness		Avg. GT
Measured			2,051,000				994,000			0.10%		5.35		0.552
Indicated			595,000				474,000			0.06%		5.92		0.371
Total M&I			2,646,000				1,468,000			0.09%		5.49		0.495
December 31, 2024, Non-ISR Only (GT cutoff 0.10)
		Pounds				Tons				Avg. Grade		Avg. Thickness		Avg. GT
Indicated			515,000				563,236			0.05%		5.84		0.267
Total M&I			515,000				563,236			0.05%		5.84		0.267

Notes:

1. Mineral resources as defined in 17 CFR § 229.1300 and as used in NI 43-101.

2. All ISR Only resources occur below the static water table.

3. The point of reference for mineral resources is in-situ at the Project.

4. Mineral resources that are not mineral reserves do not have demonstrated economic viability.

5. An 80% metallurgical recovery factor was considered for the purposes of the economic analysis.

6. Totals may not sum due to rounding

Table 14.6.  Central Unit Inferred Mineral Resource Summary

December 31, 2024 (GT Cutoff 0.10)
		Pounds				Tons				Avg. Grade		Avg. Thickness		Avg. GT
Inferred			128,000				140,000			0.05%		5.23		0.239
December 31, 2024, ISR Only (GT Cutoff 0.10)
		Pounds				Tons				Avg. Grade		Avg. Thickness		Avg. GT
Inferred			92,000				88,000			0.05%		4.46		0.233
December 31, 2024, Non-ISR Only (GT cutoff 0.10)
		Pounds				Tons				Avg. Grade		Avg. Thickness		Avg. GT
Inferred			36,000				52,000			0.03%		5.82		0.2

Notes:

1. Mineral resources as defined in 17 CFR § 229.1300 and as used in NI 43-101.

2. All ISR Only resources occur below the static water table.

3. The point of reference for mineral resources is in-situ at the Project.

4. Mineral resources that are not mineral reserves do not have demonstrated economic viability.

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14.4.3 Rock Hill

Resources at Rock Hill are shallow, averaging approximately 40 feet in depth from surface, and have, at least in part, been re-distributed by surface oxidation. Data from close spaced drilling (50 foot) is available. Tables 14.7 and 14.8 summarize the mineral resources estimated for Rock Hill, which are entirely Non-ISR resources.

Table 14.7.  Rock Hill Measured and Indicated Mineral Resource Summary

December 31, 2024, Non-ISR Only (GT cutoff 0.10)
		Pounds				Tons				Avg. Grade		Avg. Thickness		Avg. GT
Indicated			984,000				1,195,000			0.04%		15.83		0.652
Total M&I			984,000				1,195,000			0.04%		15.83		0.652

Notes:

1. Mineral resources as defined in 17 CFR § 229.1300 and as used in NI 43-101.

2. The point of reference for mineral resources is in-situ at the Project.

3. Mineral resources that are not mineral reserves do not have demonstrated economic viability.

Table 14.8.  Rock Hill Inferred Mineral Resource Summary

December 31, 2024, Non-ISR Only (GT cutoff 0.10)
		Pounds				Tons				Avg. Grade		Avg. Thickness		Avg. GT
Inferred			19,000				42,000			0.02%		10.4		0.234

Notes:

1. Mineral resources as defined in 17 CFR § 229.1300 and as used in NI 43-101.

2. The point of reference for mineral resources is in-situ at the Project.

3. Mineral resources that are not mineral reserves do not have demonstrated economic viability.

14.4.4 South Black Mountain

South Black Mountain drill data consists of 20 drillholes from relatively recent drilling (2007-2013) and 41 drillholes from pre-2007. Two mineralized horizons are present in the area occurring at depths of approximately 980 feet and 1100 feet. South Black Mountain is located south of the Beaver Rim and contains the deepest mineralization of the Project. The area has been untouched by historic mining. Tables 14.9 and 14.10 summarize the mineral resources estimated for South Black Mountain, which are entirely ISR amenable resources.

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Table 14.9. South Black Mountain Measured and Indicated Mineral Resource Summary

December 31, 2024, ISR Only (GT cutoff 0.10)
		Pounds				Tons				Avg. Grade		Avg. Thickness		Avg. GT
Indicated			859,000				525,730			0.08%		4.43		0.362
Total M&I			859,000				525,730			0.08%		4.43		0.362

Notes:

1. Mineral resources as defined in 17 CFR § 229.1300 and as used in NI 43-101.

2. All ISR Only resources occur below the static water table.

3. The point of reference for mineral resources is in-situ at the Project.

4. Mineral resources that are not mineral reserves do not have demonstrated economic viability.

5. An 80% metallurgical recovery factor was considered for the purposes of the economic analysis.

Table 14.10. South Black Mountain Inferred Mineral Resource Summary

December 31, 2024, ISR Only (GT cutoff 0.10)
		Pounds				Tons				Avg. Grade		Avg. Thickness		Avg. GT
Inferred			35,000				31,000			0.06%		3.48		0.2

Notes:

1. Mineral resources as defined in 17 CFR § 229.1300 and as used in NI 43-101.

2. All ISR Only resources occur below the static water table.

3. The point of reference for mineral resources is in-situ at the Project.

4. Mineral resources that are not mineral reserves do not have demonstrated economic viability.

14.4.5 Jeep

A single mineralized horizon is present in the Jeep area occurring at an approximate depth of 270 feet. Tables 14.11 and 14.12 summarize the mineral resources estimated for the Jeep area, which are entirely ISR resources.

Table 14.11. Jeep Measured and Indicated Mineral Resource Summary

December 31, 2024, ISR Only (GT cutoff 0.10)
		Pounds				Tons				Avg. Grade		Avg. Thickness		Avg. GT
Indicated			489,000				288,000			0.09%		5.1		0.433
Total M&I			489,000				288,000			0.09%		5.1		0.433

Notes:

1. Mineral resources as defined in 17 CFR § 229.1300 and as used in NI 43-101.

2. All ISR Only resources occur below the static water table.

3. The point of reference for mineral resources is in-situ at the Project.

4. Mineral resources that are not mineral reserves do not have demonstrated economic viability.

5. An 80% metallurgical recovery factor was considered for the purposes of the economic analysis.

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Table 14.12. Jeep Inferred Mineral Resource Summary

December 31, 2024, ISR Only (GT cutoff 0.10)
		Pounds				Tons				Avg. Grade		Avg. Thickness		Avg. GT
Inferred			7,000				7,000			0.06%		3.75		0.206

Notes:

1. Mineral resources as defined in 17 CFR § 229.1300 and as used in NI 43-101.

2. All ISR Only resources occur below the static water table.

3. The point of reference for mineral resources is in-situ at the Project.

4. Mineral resources that are not mineral reserves do not have demonstrated economic viability.

14.5 GT Contour Maps

GT contour maps for the five mineral resource areas: Central Unit, West Unit, Rock Hill, South Black Mountain, and Jeep are provided as Figures 14.2 through 14.9. The GT Contour maps provide a graphical representation or model of the mineralization reflecting the location, quality represented by GT, location of drill holes and continuity of the mineralization.

14.6 Discussion on Mineral Resources

Mineral resources do not have demonstrated economic viability, but they have had technical and economic constraints applied to them to establish reasonable prospects for eventual economic extraction. The geological evidence supporting measured and indicated mineral resources is derived from adequately detailed and reliable exploration, sampling and testing, and is sufficient to reasonably assume geological and grade continuity. The measured and indicated mineral resources are estimated with sufficient confidence to allow the application of technical, economic, marketing, legal, environmental, social and governmental factors to support mine planning and economic evaluation of the economic viability of the deposit.

The tons and grade of the inferred mineral resources are estimated on the basis of limited geological evidence and sampling, but the information is sufficient to imply, but not verify, geological and grade continuity. The Authors expect the majority of inferred mineral resources could be upgraded to indicated mineral resources with additional drilling.

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Figure 14.2. West Unit A Sand GT Contour Map

Gas Hills Uranium Project Technical Report – February 2025 Page 57

Figure 14.3. West Unit B Sand GT Contour Map

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Figure 14.4. Central Unit A Sand GT Contour Map

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Figure 14.5. Central Unit B Sand GT Contour Map

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Figure 14.6. Rock Hill GT Contour Map

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Figure 14.7. South Black Mountain A Sand GT Contour Map

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Figure 14.8. South Black Mountain B Sand GT Contour Map

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Figure 14.9. Jeep GT Contour Map

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15.0 MINERAL RESERVES

Mineral reserves were not estimated for this Report.

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16.0 MINING METHODS

This section of the Report describes extraction and uranium processing, the cost estimate approach and assumptions used to develop the capital and operating costs. The mining method addressed in this Report is ISR. There is no excavation of ore and no mining dilution with this method. Only minerals that can be taken into solution are recovered.

16.1 Mineral Deposit Amenability

enCore plans to use the ISR mining technique with a low pH lixiviant at the Project. As discussed in Section 6.0, the Gas Hills was one of the major uranium mining and production regions in the USA with cumulative production in excess of 100 million pounds of uranium, mainly from open-pit mining, but also from underground and ISR mining methods. This historical production demonstrated the host Wind River Formation sandstones and the hydrological conditions to be suitable for ISR production.

ISR is employed because this technique allows for the low cost and effective recovery of roll front mineralization. An additional benefit is that ISR is relatively environmentally benign when compared to conventional open pit or underground recovery techniques. ISR does not require the installation of tailings facilities or require significant surface disturbance.

This mining method utilizes injection wells to introduce a lixiviant into the mineralized zone. This Report assumes a low pH lixiviant will be utilized in the ISR process. Low pH ISR lixiviants have technical and economic advantages over alkaline lixiviants in formations that have relatively low carbonate content and amenable geology. These advantages include potential for higher recovery, shorter leaching duration, lower lixiviant and oxidant requirements, constituent-specific advantages during groundwater restoration, and a higher degree of natural attenuation than alkaline lixiviant. The lixiviant is made of native groundwater fortified with a complexing agent such as sulfuric acid. The complexing agent bonds with the uranium to form uranyl sulfate, which is then recovered through a series of production wells and piped to a processing plant where the uranyl sulfate is removed from solution using ion exchange. The groundwater is re-fortified with the complexing agent and recirculated to the wellfield to recover additional uranium.

In order to use the ISR technique, the mineralized body must be saturated with groundwater, transmissive to water flow, and amenable to dissolution by an acceptable lixiviant. While not a requirement, it is beneficial if the production zone aquifer is relatively confined by overlying and underlying aquitards in order to maintain control of the mining lixiviant. Available geophysical data indicate that there are confining intervals between the targeted sands and vertically adjacent aquifers. As described in Section 14, mineralization has been mapped in two different sand intervals, referred to as the A Sand and the B Sand each of which was further divided into three sub-sands (A1, A2, A3, B1, B2, B3). Based on drilling logs, each individual mineralized sand is

Gas Hills Uranium Project Technical Report – February 2025 Page 66

generally bounded on top and bottom by a lower permeability layer. As such, for the purposes of this analysis it was assumed that each sand lens would be separately mined with its own set of wells. As discussed in Section 7.5, groundwater quality and water level data have been monitored at the Project for more than three decades. A 2021 numerical groundwater flow model developed within the ISR resource areas in the Central Unit indicated ISR operations could be sustained in a life-of-

mine production scenario with much of the water column above the immediate mining zone remaining intact during ISR operations (Hydro-Engineering, 2021). See Sections 7.5 and 16.2 for additional discussion.

Several agitation leach (bottle-roll) and column leach tests have been carried out on core samples from the Project to ensure leachability with an acceptable lixiviant. Test results in Section 13.0 show that recoveries of approximately 90 percent are technically possible; however, this Report assumes a recovery of 80 percent of the uranium in each wellfield pattern. See Section 13.0 for a complete discussion of leach test results.

16.2 Hydrology

16.2.1  Hydrogeology

The regional geology and Project stratigraphy are discussed in detail in Section 7.0 of this report and are not repeated here. What follows is a discussion of the hydrologic regime and its relevance to ISR mining.

Within the Project area, the Wind River Formation is the primary aquifer system containing mineralization. The relatively large distance between mining units means that each individual mine unit is, for all practical purposes, hydrologically independent. Each individual mineralized sand lens is generally bounded on top and bottom by strata with lower permeability. In effect, this means that at a local scale the uranium bearing sand lenses have varying levels of hydraulic separation from other overlying and underlying sands which are also located within the Wind River Formation. These areas of local confinement do not extend across the entire Project and sands within the Wind River Formation are regionally in the same aquifer. Based on available water level monitoring data, groundwater levels within the Project area are still recovering from historical mining activities which ceased circa 1980. The water levels with respect to ISR targeted mineralized sands in each mine unit are summarized as follows:

• West Unit, available water level information indicates there is between 16 and 333 feet of head over the top of the West Unit ISR resources. Within the West Unit there are three ore bodies located adjacent to or spanning across the section line between Sections 11 and 14 (T32N R91W). In this area geology is complicated with a fault likely passing through one of the delineated ore bodies and a horst located to the east of the ore bodies. Wells north and south of the fault show a steep water level gradient. Similarly, the fault likely impacts ore bodies to the east located along the eastern portion of the section line between Sections 12 and 13 of T32N, R91W. Available data suggests that there is at least

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34 feet of head above these ore bodies (Michel, 2021). The presence of the fault raises some uncertainties in the estimated water level elevation in this area. As such, additional characterization of the aquifer properties will be required to verify conditions at these ore bodies. As noted in Section 14, resources in these areas were put into the inferred category due to uncertainty in aquifer conditions.

• Central Unit, water level information indicates that within the three portions of the unit where orebodies have been mapped, minimum water levels over the shallowest ISR ore bodies range from 10 to 40 feet (Michel, 2021) with the deeper ore bodies having 93 feet or more of available head (Hydro-Engineering, 2021). Hydro-Engineering conducted their ISR modeling study within the George-Ver Mine area which is located within the Central Unit.

• South Black Mountain, available water level and aquifer properties information is very limited in the South Black Mountain area. However, projection of water level information from available data to the north indicates that water levels will generally be in the range of 230 feet to 410 feet above the ore bodies (Michel, 2021).

• Jeep, available water level and aquifer properties information is not available in the Jeep area. Projections of water levels from the West Unit to Jeep indicate that water levels are sufficiently high enough to provide adequate head for ISR operations (Michel, 2021).

Groundwater flow modeling conducted by Hydro-Engineering was performed to predict water level elevation changes that may result from ISR mining operations. The modeling predicted drawdowns could range from two to seven feet (Michel 2021). Comparing available water level information with modeling results indicates there is likely sufficient head for ISR operations to be successful at the ISR targeted resources in the West Unit and Central Unit. While it is currently assumed sufficient head is available, additional evaluations will be necessary to confirm water level assumptions within Jeep, South Black Mountain, and portions of the West Unit and Central Unit.

In 2018 Hydro-Engineering analyzed Wind River aquifer hydraulic properties using available aquifer testing data for historic mining areas within the West Unit (Day Loma and Loco Lee), Central Unit (Bullrush and George-Ver), and Cameco’s properties to the south and east of the central unit. However, there is no aquifer testing data available within either the Jeep or the South Black Mountain areas. Aquifer properties are described in the 2018 Hydro-Engineering report as follows:

• West Unit. Within the West Unit, aquifer testing was conducted in 2010 in the historic Day Loma mining area which is in the southeast portion of the Unit. Aquifer testing results indicate that expected hydraulic conductivities range from 1.8 to 2.9 ft/day within the Wind River aquifer in the Day Loma area.

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• Central Unit. Within the historic George-Ver mining area located in the northeast portion of the Central Unit, aquifer tests have been conducted in 1979, 1990, and 2008. The tests demonstrated that hydraulic conductivities in the range of 2.3 to 4.1 ft/day are considered representative. Within the historic Bullrush mining area located in the northwest portion of the Central Unit, hydraulic conductivities ranged from 0.8 to 13.4 ft/day based on results of tests conducted in 2010 and 2011. Hydro-Engineering speculates the Sagebrush fault running through the Bullrush area may have affected the results on both the high and the low side and it is plausible that the typical range of hydraulic conductivities in the Bullrush area is more likely to be between 1.0 and 5.7 ft/day outside of the influence of the fault.

• Cameco Mine area. A number of aquifer tests have been conducted in the Cameco Mine Area located to the southeast of the Central Unit. Hydro-Engineering evaluated aquifer test results which were submitted to regulatory agencies and a large number of results were in the range of 0.5 to 6 ft/day. Hydro-Engineering determined that a typical hydraulic conductivity within the Cameco Area is between 1 to 2 ft/day.

The results of the available testing are reasonably consistent from one property to another over an area some 6-8 miles across. While no actual test data is available in the Jeep or South Black Mountain units, it is not unreasonable that hydraulic properties in these areas are consistent with those in the areas where test data is available. Aquifer test results conducted within the West Unit, Central Unit and Cameco properties demonstrate that, while there is some heterogeneity in aquifer properties, typical hydraulic conductivities are high enough to allow for ISR mining. Hydraulic conductivities of 1.0 ft/day or greater are expected within the proposed mining areas based on test results to date. For comparison Hydro-Engineering (2018) evaluated typical hydraulic conductivities within Ur Energy’s Lost Creek Project (approximately 50 miles south of the Gas Hills) and found that the hydraulic conductivities, which averaged between 0.66 ft/day to 1.69 ft/day, are slightly lower than those that could be expected the Gas Hills. Given the success of the Lost Creek Project, it is reasonable to assume that aquifer conditions in the Wind River aquifer within the Gas Hills are generally sufficient for ISR operations.

16.2.2 Historical Drill Holes

Due to the extensive exploration and ore deposit delineation in the Gas Hills Uranium District, there are a large number of historical drill holes within the Project area. Most of the drillholes date back to the 1950’s through the 1970’s and much of the historical drilling is poorly documented. Additionally, due to open pit mine reclamation efforts and regrading of the ground surface it may not be possible to locate many of these historic drill holes on the surface. From an ISR mining perspective historical drill holes can be problematic. If the drill holes have not been plugged nor naturally collapsed and sealed off, they can represent a potential path for ISR mining fluids to migrate vertically into other aquifers. In this case, migration would be coming from ISR mining fluids within the Wind River Formation. This project is unique in that the targeted aquifer for

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mining is also the uppermost aquifer in all mine units except possibly South Black Mountain. Within the South Black Mountain unit, the Split Rock Formation may overlie the ore bearing aquifer. The Split Rock Formation is known to be a water bearing aquifer in the region. Given the proximity to the outcrop, it is likely that the Split Rock Formation is dry within the South Black Mountain unit. Nevertheless, additional evaluations will be required to verify whether there is an overlying aquifer to protect at South Black Mountain. Generally, within this Project, there is no additional overlying aquifer between the aquifer to be mined and the surface. Therefore, there is no aquifer to be potentially impacted by vertical migration of ISR mining fluids upwards into an overlying aquifer. Protection of aquifers underlying the Wind River Formation is also a consideration. Historical drilling focused on shallow deposits that could be economically mined with open pit methods. Historic mining activity occurred within the Wind River Formation. Historic drill hole data possessed by enCore indicates none of the holes penetrate past the Wind River Formation nor through the underlying Cody Shale confining aquitard. Because of the relatively shallow drilling depth and lack of an overlying aquifer, historic drill holes are not anticipated to present a problem with containment of ISR mining fluids and no plugging program is assumed to be necessary. Unsealed boreholes are not expected to provide a pathway to impact any overlying or underlying aquifers. Additional aquifer tests will be conducted in each mine area prior to mining to further evaluate the potential for historical drill holes to impact mining operations or their potential to impact aquifers outside of proposed ISR operations.

16.3 Conceptual Wellfield Design

The most fundamental component of ISR mine development and production is the production pattern. A pattern consists of one production well and multiple injection wells which feed lixiviant back to the production well. Injection wells are commonly shared by multiple production wells. Header houses serve multiple patterns and function as both distribution points for injection flow and collection points for production flow. The CPP feeds injection lixiviant to the header houses for distribution to the injection wells and also receives and processes production flow from the header houses.

16.3.1 ISR Amenable Resources

The total resource base was evaluated based on physiographic and depth criteria to judge whether it is minable with current ISR mining methods. The evaluation determined that portions of the total mineral resource are not minable using current ISR methods for the purpose of this Report, those portions of the mineral resource were excluded from economic consideration. These excluded resources are still available to non-conventional ISR techniques and other mining methods.

For conventional ISR mining operations, it is necessary that the uranium resources be located below the static water table. Resources that are generally above the water table are not considered amenable by ISR methods and classified as Non-ISR in the mineral resource summary tables. The resources available for ISR mining in each unit are summarized in Section 14. As discussed in Section 16.2.1, available data indicates

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there is likely sufficient head for successful ISR mining operations in the ISR resources described in Section 14.

16.3.2 Wellfield Patterns

The Project is planned to be developed using both 5-spot and 7-spot wellfield patterns. The planned 5-spot wellfield pattern configuration consists of four injection wells 100 ft apart squarely placed around a central production well, resulting in a pattern area of approximately 10,000 ft². The planned 7-spot wellfield pattern configuration consists of six injection wells spaced 115 ft apart in a hexagonal configuration around a central production well resulting in a pattern area of approximately 34,360 ft². Actual pattern geometry may vary depending on field conditions. Based on preliminary wellfield designs, it is anticipated that incorporating both 5-spot and 7-spot patterns into the wellfield design will result in an average pattern size of approximately 17,000 ft² for the Project. The pattern size was used in conjunction with the total acreage associated with the resources that may potentially be mined with ISR methods to estimate the total number of patterns necessary for the Project. This approach to estimating preliminary wellfield infrastructure requirements is comparable to the work conducted at other ISR mines in Wyoming.

In plan-view, patterns will be designed to overlay mapped roll fronts. Well completion intervals in each pattern will be carefully evaluated using available data to optimize lixiviant flow paths through targeted resources. In some areas, there are multiple stacked roll fronts in the same vicinity. Operational experience has demonstrated the optimum injection/production well completion thickness to be between 10 and 25 ft. Consequently, the multitude of individually mapped fronts in portions of the Project results in the “stacking” of wellfield areas. This occurs when two or more mining completions are planned for the same pattern area in an overlapping fashion. This is due to multiple mineralized horizons or the presence of more mineralized thickness than can be efficiently mined with a single well completion. For the purposes of this analysis, it was assumed that none of the wells would target more than one roll front. As such, where there are multiple stacked roll fronts in the same pattern area a separate pattern will be planned for each roll front and each well completion will only target one roll front.

The Project-wide wellfield area has been divided into four resource areas with ISR amenable mineralization as described in Section 14.4: Figures 14.2-14.5 and 14.7-14.9 illustrate the distribution of resources within the resource areas. The dimensions of each resource area are summarized on Table 16.1. Based on an average pattern area of approximately 17,000 ft² the Project would require an estimated 863 patterns. Within these mine units, 1,726 injection wells and 863 production wells are estimated, using a 2:1 injection to production well ratio, for a total of 2,589 wells (Table 16.1). The number of wells in each unit are based the assumption that 100 percent of South Black Mountain wellfields are 5-spot patterns, 50 percent of Jeep wellfields are 5 spot patterns, 20 percent of Central Unit wellfields are 5 spot patterns, and 36 percent of the West Unit wellfields are 5 spot patterns. The average estimated well completion thickness for the Project is 7.5 ft. The number of patterns estimated for each resource

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area is then used to calculate an average recoverable resource per pattern, as shown in Table 16.1.

Table 16.1. Development Summary by Resource Area

Resource Area		Resource (lbs. x 1000)1		Recoverable Resource (lbs. x 1000)2		Average Recoverable lbs./Pattern		Injection Wells		Production Wells		Wellfield area (ac)		Average Well Depth (ft.)3
South Black Mountain		894		687		2,991		460		230		53		1,047
Jeep		496		391		6,031		132		66		23		285
Central		2,739		2,117		10,090		422		211		111		208
West		4,004		2,969		8,385		712		356		148		284
Project Total		8,133		6164		6,875		1,726		863		335		380

¹ Sum of pounds may not add to the reported total due to rounding.

²Recoverable resources exclude all the inferred resources and assume 80 percent of the measured and indicated resources are recovered.

³ Project totals reflect weighted average.

16.3.3 Monitor Wells

To meet regulatory requirements, perimeter monitor wells will surround each mine unit at a spacing no greater than 500 ft. from each other and no greater than 500 ft. from the nearest production pattern. Monitor wells interior to the wellfield are also required on a one well per 4-acre spacing within areas covered by patterns. These interior wells typically consist of monitor wells completed in the overlying aquifer, the underlying aquifer and the production zone. However, the Wind River production zone is the uppermost aquifer. Therefore, the interior monitor wells are assumed to consist of only underlying and production zone monitor wells. These wells will be placed in clusters evenly distributed through each mine unit, with each cluster composed of one of each type of well. For the purposes of this Report, no detailed analysis of the number and locations of the monitor wells was completed. Rather wellfield costing numbers were taken from the Shirley Basin PEA prepared for Ur Energy in 2024. The monitor well depths and density in the Shirley Basin Project are expected to be similar to those in the Gas Hills project. The one difference is that the Shirley Basin Uranium project has no underlying monitor wells while the Gas Hills Project has no overlying monitor wells.

16.3.4 Mining Schedule

The mine life sequence can be described as development, production and groundwater restoration followed by surface reclamation (Figure 16.1). Construction activities which include delineation drilling, deep disposal test well investigation and installation of initial monitor wells are planned to begin after permitting is complete which is estimated to be in the third quarter of Year-1.

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Figure 16.1. Life of Mine Schedule

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Production is estimated to begin in Year 1 and continue into Year 7. Annual production is estimated to be approximately one million pounds per year. Restoration and reclamation activities are scheduled to start soon after production is completed in a mine unit. Final decommissioning will occur simultaneously with reclamation of the last production area.

16.4 Piping

Pipelines transport the wellfield solutions to and from the planned CPP at the West Unit and to the disposal well. The flow rates and pressures of the individual well lines are monitored in the header houses. Flow and pressure of the field production systems are also monitored and controlled as appropriate at the header houses. High density polyethylene (HDPE), PVC, stainless steel, or equivalent piping is used in the wellfields and will be designed and selected to meet designed operating conditions. The pipelines from the CPP, header houses, and individual well lines will be buried for freeze protection and to minimize pipe movement. Generally, the pipelines within the wellfields are relatively small diameter pipes designed to carry flows in the range of 10 to 50 gpm. These pipelines are typical of most comparable ISR projects, and the costs associated with installing them are included in the wellfield installation costs. The Gas Hills Project is unique in that there is a large distance between each unit. Several larger diameter pipelines will transfer water between mine units Figure 16.2 shows the general schematic of the pipeline layout for the project. These pipelines were considered separately in this analysis because of their uniqueness to this project. The larger diameter transfer pipelines will likely be constructed using HDPE and include the following:

• 2-12-inch-diameter pipelines running between the West Unit and the Jeep Unit. Pipeline lengths are estimated at 24,000 feet.

• 4-16-inch-diameter pipelines running between the West Unit and Central Unit. Pipeline lengths are estimated at 25,400 feet.

• 2-16-inch diameter pipelines between the South Black Mountain unit and the CPP in the West Unit. Pipeline lengths are estimated at 27,400 feet.

• Booster pump stations will be installed as necessary to maintain adequate pressure in the pipelines.

16.5 Header Houses

Header houses are used to distribute lixiviant injection fluid to injection wells and collect pregnant solution from production wells. Each header house is connected to two trunk lines, one for receiving barren lixiviant from the CPP and one for conveying pregnant solutions to the CPP. The header houses include manifolds, valves, flow meters, pressure gauges, and instrumentation. Each header house is assumed to service approximately 75 wells (injection and production).

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Figure 16.2. Pipeline Infrastructure Map

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16.6 Wellfield Reagents and Electricity

The evaluation presented in this report assumes flowrates at the CPP/wellfield will be very similar to those in the Dewey-Burdock facility. Given the similarities in operational details reagent and electricity use costs are expected to be similar to those calculated for the Dewey-Burdock PEA. The one difference is that the low pH recovery will use sulfuric acid rather than oxygen and sodium bicarbonate or similar. The sulfuric acid is expected to increase the chemical costs by up to $2.66/lb of U₃O₈ produced.

16.7 Mining Fleet Equipment and Machinery

Equipment and machinery will be required to support the installation and operation of wellfields, a CPP and post-mining reclamation activities. Given the preliminary state of the Gas Hills project design, a detailed list of the equipment needs has not yet been developed. Rather costs for the equipment are estimated based on costs developed for the Dewey-Burdock Project for which designs are further advanced. It is assumed that a similar level of equipment and machinery will be required for the Gas Hills Project.

16.8 Labor

Labor requirements for the Project are based on estimates for the Dewey-Burdock Project. Based on Dewey-Burdock level staffing it is estimated that up to 43 employees will be necessary to operate the project at full production. This includes 7 employees in administration, 16 employees necessary for wellfield construction, 15 employees to operate the CPP, and 7 employees for wellfield production/restoration. The actual number of employees at any time will vary depending on how many wellfields are in operation and the phase of the Project.

17.0 RECOVERY METHODS

ISR operations consist of four major solution circuits, ion exchange to extract uranium from the mining solution, an elution circuit to remove uranium from the IX resin, a yellowcake precipitation circuit, and a dewatering, drying, and packaging circuit.

Figure 17.1 presents a simplified process flow diagram.

17.1 CPP Operations

Production fluid containing dissolved uranyl sulfate from the wellfields is pumped to the CPP plant for beneficiation as described below. The plant considered in this Report will have an available flow rate of 4,400 gpm. However, the planned average production flow rate for the Project is approximately 2,400 gpm. Processes used at the CPP to recover uranium will include the following circuits:

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Figure 17.1. Process Flow Diagram

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• Resin Loading (IX circuit).

• Resin Elution.

• Uranium Precipitation.

• Uranium Product Washing, Drying and Packaging.

IX Circuit – The IX circuit will be housed in a metal building which will also house the resin transfer equipment as well as the restoration circuit. Uranium liberated from the underground deposits is extracted from the pregnant solution in the IX circuit. Pregnant lixiviant from the wellfields enters the IX column (typically a pressurized down-flow system to contain radon gas and progeny in solution) and passes through the bed of IX resin. The ion-specific resin captures anionic uranium complexes in exchange for common anions such as chloride and bicarbonate. The barren lixiviant exiting the IX loading stage will ideally contain less than 2 ppm of uranium. Subsequently, the barren lixiviant is reconstituted, as needed, and pH is corrected prior to being pumped back to the wellfield for reinjection. A low-volume bleed is permanently removed from the lixiviant flow to maintain an inward gradient within the wellfields. The wellfield bleed is disposed of by injection into an Underground Injection Control (UIC) Class I Deep Disposal Well (DDW). See Section 17.4 for a detailed description of the planned wastewater management system.

During groundwater restoration activities, the bleed is treated by reverse osmosis (RO) to remove metals and salts (e.g., calcium, sodium, sulfate) and the clean permeate is reused in the process. This clean permeate is of better quality than the native groundwater. The RO brine is then disposed of by injection into the DDW.

Elution Circuit – The elution process reverses the loading reaction which occurred in the IX circuit and removes the uranium from the resin. The elution circuit also regenerates the resin’s exchange capacity by replacing uranium ions on the resin. A brine solution, sodium chloride and sodium carbonate, is added to elution vessels containing loaded resin. Uranium complexes will then be contained in the rich eluate solution, which leaves the elution circuit for further processing.

Precipitation Circuit – The purpose of the precipitation circuit is to break down the uranium complexes and precipitate the uranium as uranium peroxide slurry. Multiple precipitation tanks in series with mechanical agitators will accomplish the steps needed to form the slurry. Precipitation chemicals include sulfuric acid, caustic soda, and hydrogen peroxide.

First, the sulfuric acid is added to the rich eluate to break down the uranium complexes. Then sodium hydroxide (caustic soda) is added to the solution to raise the pH. After this pH adjustment, hydrogen peroxide is added in a continuous circuit to precipitate an insoluble uranyl peroxide (UO₄) compound.

Product Filtering, Drying and Packaging – After precipitation, the uranium precipitate, or yellowcake slurry, is removed for washing, filtering, drying, and product packaging in a controlled area. The yellowcake from the precipitation tank is filtered and washed

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in a filter press to remove excess chlorides and other soluble contaminants. The filter cake is re-slurried with clean water and then transferred to the yellowcake dryer. The yellowcake is dried in a vacuum dryer, which is completely enclosed during the drying cycle to prevent air emissions.

The packaging equipment is located directly below the dryer and includes a discharge chute, rotary airlock valve, ventilated drum hood, and drum conveyor. Yellowcake will be packaged into 208.4-liter drums, weighed and labeled, and prepared for shipment/storage.

Associated with the CPP will be office, construction, maintenance, warehouse and drilling support buildings. CPP construction is expected to commence in Year -2 upon the receipt of the last required permit.

17.2 Transportation

For the purposes of this Report, it has been assumed that drummed yellowcake will be shipped via truck approximately 1,500 miles to the conversion facility in Metropolis, Illinois. This conversion facility is the first manufacturing step in converting the yellowcake into reactor fuel.

17.3 Energy, Water and Process Materials

As discussed in Section 16.6, the Gas Hills CPP will generally be similar in flow rates and operation as the planned CPP at the Dewey-Burdock facility for which the design is much further advanced. Except for the change to sulfuric acid, energy and reagent use are expected to be similar to the costs associated with Dewey-Burdock. For the purposes of this Report costs and assumptions developed for Dewey-Burdock were used to prepare cost estimates herein and adjusted as necessary for increased sulfuric acid costs and inflation. The low pH recovery methods are expected to result in higher headgrades and lower water flow rates than the alkaline recovery methods considered in Dewey-Burdock. No reductions in operational costs were made to adjust for this change.

17.4 Liquid Disposal

Typical ISR mining operations generate limited quantities of wastewater that cannot be returned to the production aquifers. The wastewater will be derived from two sources: wellfield production bleed and CPP processes. The production bleed is a net withdrawal of water that generates an area of low hydrostatic pressure within the mining zone. Water surrounding the mining zone flows toward the area of low pressure thereby preventing mining solutions from migrating away from the mining zone toward protected waters. The wellfield production bleed rate is estimated at 0.5 to 1.0 percent of the total mine flow rate. The rate of liquid wastes generated from the facility at the planned average production flow rate of 2,400 gpm facility will be approximately 22 gpm for deep disposal. One DDW is planned for the Project. The CAPEX and OPEX

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estimates for this Report assume that this well will support the production and restoration operations.

Restoration wastewater treatment will entail passing portions of the fluid through a RO system. Permeate from the RO will return to the wellfield, while the brine (RO reject fluid) will be injected into the DDW.

17.5 Solid Waste Disposal

Solid wastes consist of empty packaging, miscellaneous pipes and fittings, tank sediments, used personal protective equipment and domestic trash. These materials are classified as contaminated or non-contaminated based on their radiological characteristics.

Non-contaminated solid waste is waste which is not contaminated with radioactive material or contaminated waste which can be decontaminated and re-classified as non-contaminated waste. This type of waste may include trash, piping, valves, instrumentation, equipment and any other items which are not contaminated, or which may be successfully decontaminated. Current estimates from similar uranium ISR facilities are that the site will produce approximately 700 cubic yards of non-contaminated solid waste per year. Non-contaminated solid waste will be collected in designated areas at the Project site and disposed of within an approved industrial solid waste landfill.

Contaminated solid waste consists of solid waste contaminated with radioactive material that cannot be decontaminated. This waste will be classified as 11e.(2) byproduct material as defined by NRC regulations. This byproduct material consists of filters, personal protective equipment, spent resin, piping, etc. 11e.(2) byproduct material will be shipped by truck for disposal at a licensed disposal site which is capable of handling these materials. It is estimated that the Project will produce approximately 90 cubic yards of 11e.(2) byproduct material as waste per year. This estimate is based on the waste generation rates of similar uranium ISR facilities.

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18.0 PROJECT INFRASTRUCTURE

18.1 Roads

Four types of roads will be used for access to the Project and its production areas. They include primary access roads, secondary access roads, temporary wellfield access roads, and well access roads. The Project area is served by County Road 212 (Gas Hills Road). Gas Hills Road is a county maintained, two-lane, gravel road providing year around access. Access to the Project from the north (Casper) is via US Highway 20/26, access from the west (Riverton) is from Wyoming Highway 136, and access from the south (Lander or Rawlins) is via US Highway 287. The proposed access to the ISR production areas will require upgrading existing all-weather access roads which are reached by the Gas Hills Road.

Snow removal and periodic surface maintenance will be performed as needed. The secondary access roads are used at the Project to provide access to the wellfield header houses. The secondary access roads are constructed with limited cut and fill construction and may be surfaced with small sized aggregate or other appropriate material.

The temporary wellfield access roads are for access to drilling sites, wellfield development, or ancillary areas assisting in wellfield development. When possible, enCore will use existing two-track trails or designate two-track trails where the land surface is not typically modified to accommodate the road. The temporary wellfield access roads will be used throughout the mining areas and will be reclaimed at the end of mining and restoration.

18.2 Electricity

Electrical power for the CPP on the West Unit will be provided by an existing 3-phase transmission line along the western edge of the unit and electrical power for the Central Unit will be provided by an overhead 3-phase power line feeding an existing substation at the historic George Ver facility site. Overhead 3-phase power is also available immediately adjacent to the Jeep project. To get overhead power to the South Black Mountain project approximately 1.5 miles of powerline will need to be constructed. Power lines from header houses to production wells will be placed underground using direct burial wire.

18.3 Holding Pond

The cost estimate also includes capital costs to construct a holding pond to contain process wastewater when the DDW is shut down for maintenance and annual testing. The earthen banked pond will be designed to hold 30 days’ worth of wastewater. The pond will have a double lined containment system with leak detection between the liners. The same rigorous designs have been established to ensure proper inspection, operation, and maintenance of the holding ponds at other similar projects in Wyoming, and it is anticipated that they will be applied at the Project as well.

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19.0 MARKET STUDIES AND CONTRACTS

Unlike other commodities, uranium does not trade on an open market. Contracts are negotiated privately between buyers and sellers. Sales contracts vary in quantity and duration from spot market transactions, typically one-time, near-term deliveries involving as little as 25,000 lbs. U₃O₈, to long term sales agreements covering deliveries over multiple future years with quantities in the hundreds of thousands to millions of pounds of U₃O₈. A fixed sales price of $88 per lb U₃O₈ was assumed for this analysis. The sales price was developed based on price projections provided in a proprietary report developed by Trade Tech, 2023. In the proprietary report Tradetech estimated the term price would vary between $85 per lb up to $89 per lb between 2029 and 2038. The average projected price over this period is approximately $87 per lb. This price compares favorably with current uranium prices experienced in the 2^nd half of 2024. The QP has also evaluated less comprehensive but more recent market evaluations (Sprott, 2024 and 2025, Carbon Credits.com, 2025). Generally, market experts remain bullish on Uranium prices which support the Trade Tech pricing assumptions. The QP believes these estimates are appropriate for use in the evaluation, and the results support the assumptions herein.

enCore has not entered into any uranium supply contracts that are tied to production from the Project. The anticipated sales price is considered within the sensitivities in this Report (Section 25.2). The income from estimated production at the anticipated sales price is included in the cash flow estimate.

The marketability of uranium and acceptance of uranium mining is subject to numerous factors beyond the control of enCore. The price of uranium may experience volatile and significant price movements over short periods of time. Factors known to affect the market and price of uranium include economic viability of nuclear power; political and economic conditions in uranium mining, producing and consuming countries; costs; interest rates, inflation and currency exchange fluctuations; governmental regulations; availability of financing of nuclear plants, reprocessing of spent fuel and the re-enrichment of depleted uranium tails or waste; sales of excess civilian and military inventories (including from the dismantling of nuclear weapons) by governments and industry participants; production levels and costs of production in certain geographical areas such as Asia, Africa and Australia; and changes in public acceptance of nuclear power generation as a result of any future accidents or terrorism at nuclear facilities. The economic analysis and associated sensitivities are within the range of current market variability.

During the construction phase of the plant, several contracts will be required with various construction related venders. No construction contracts have been entered into at the date of this Report. Operational purchasing agreements will be required with the primary chemical suppliers. None of these agreements have been entered. Finally, agreements will be required with a transportation company for the transport of yellowcake to the conversion facility.

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20.0 ENVIRONMENTAL STUDIES, PERMITTING AND SOCIAL OR COMMUNITY IMPACT

20.1 Environmental Studies

Extensive environmental studies, including geology, surface hydrology, sub-surface hydrology, geochemistry, wetlands, air quality, vegetation, wildlife, archeology, meteorology, background radiometrics, and soils will be required as part of the permitting process. Prior to acquiring this project, the previous owner, Strathmore Resources (US) Ltd., had developed and submitted a mine permit application for these properties to the WDEQ. The mine permit application was for open pit mining operations and not ISR. Nevertheless, much of the work completed in support of the previous permitting action will support future permitting actions. At this time, no baseline environmental studies are being performed by enCore. With the exception of possible sage grouse protection timing stipulations, there are no known environmental factors which could materially impact the permitting process or the ability to recover uranium resources.

The Project is located immediately adjacent to areas designated by the Wyoming Game and Fish Department as a core sage grouse habitat. Portions of Jeep and South Black Mountain lie within the sage grouse core area and the regulatory agencies will place timing stipulations on these portions of the Project (Wyoming Game and Fish, 2024). Although the West Unit and Central Unit lie wholly outside of the sage grouse core area, stipulations would apply due to the presence of sage grouse breeding grounds known as leks. The limitations may include limiting some activities to certain times of year.

20.2 Waste Disposal and Monitoring

20.2.1 Waste Disposal

Non-household waste generated from an ISR uranium mine generally consists of water from the wellfield and processing plant and solid waste generated from the plant, which is described in detail in Section 17. Both types of waste are classified as 11e.(2) byproduct material pursuant to the Atomic Energy Act. During production, wellfield bleed will be injected into a UIC Class I DDW.

Cameco Resources has an authorized UIC Class I DDW (Permit No. 13-262) in Section 3, T32N, R90W less than one mile to the southeast of the Central Unit as well as two additional wells east of the Central Unit and north of the South Black Mountain Unit (WDEQ 2014). Permit documentation included with the permit indicates these wells are permitted to receive up to 150 gallons of water per minute. Assuming that conditions are similar within enCore’s permit area, one DDW would be sufficient to handle projected wastewater from this facility. At this time, there are no known factors which could materially impact the feasibility of a DDW capable of disposing of the maximum estimated disposal rate necessary at the Project.

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The solid 11e.(2) waste generated at the site will consist of personal protective equipment, filters, and other used process equipment. The solid 11e.(2) byproduct material will be disposed of at an approved facility.

20.2.2 Site Monitoring

Once mining begins there will be considerable site monitoring to ensure protection of the environment and also protection of employees and the public from radionuclide effluent. Each mine unit will be surrounded laterally and vertically (where necessary) with a series of monitor wells to ensure mining solutions do not migrate out of the mining zone. The wells will be sampled twice per month with the results compared against pre-determined upper control limits (UCLs).

Significant environmental monitoring for radionuclide effluents will also take place during mining and reclamation as required by the source and byproduct material license.

Finally, wildlife monitoring will continue throughout the life of the mine and will cover a variety of species including greater sage-grouse, big game, migratory birds, fish, lagomorphs, songbirds, and other species deemed to be of concern by the regulating agencies. Third-party contractors will be utilized to perform wildlife monitoring.

20.3 Permitting

Prior to significant construction and mining, several permits/licenses from federal, state, and local agencies will be required as follows:

Federal

• EPA – Aquifer Exemption for UIC Class III wells and UIC Class I disposal wells (as necessary) and Subpart W Pond Construction Permit for the holding pond.

• BLM – Environmental Assessment (EA) and Approval of the Plan of Operations.

State

• Wyoming Department of Environmental Quality Uranium Recovery Program (WDEQ-URP) – Source and Byproduct Material License.

• WDEQ Land Quality Division (WDEQ-LQD) – Permit to Mine.

• WDEQ Water Quality Division (WDEQ-WQD) – UIC Class I Permit for deep well injection of wastewater generated from wellfield bleed and other plant processes, and Storm Water Discharge Permit which allows for surface discharge of storm water.

• WDEQ-Air Quality Division (WDEQ-AQD) – Air Quality Division, Chapter 6, Section 2, New Source Permit Authorization to Construct.

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• Wyoming State Engineer’s Office (SEO) – Various groundwater appropriation permits for ISR of uranium.

Local

• Fremont County Septic system.

Since a large portion of the project lies over federal surface, the BLM will complete the National Environmental Protection Act (NEPA) analysis for this project which will be required to approve the BLM Plan of Operation. Since the footprint of this project is less than 640 acres, BLM regulations indicate that the NEPA analysis should be an Environmental Assessment (EA) level review. For the purposes of this Report, it was assumed that the BLM would elect to do an EA level of analysis. Should BLM decide to pursue a full Environmental Impact Statement (EIS) a much more detailed analysis of potential project impacts will be required.

WDEQ-URP license preparation and review process will take approximately two years to complete. The review will include an opportunity for public comment. WDEQ-LQD, will review the permit to mine application pursuant to Noncoal Chapter 11 Rules and Regulations and will provide opportunities for public comment. The LQD review will also likely take about two years which will happen in parallel with the URP review. Following permit to mine approval, an aquifer exemption from the EPA Region 8 will be requested. The EPA will review the LQD’s request against UIC Program requirements found in 40 CFR Parts 144 and 146 to ensure compliance. If the EPA determines the operation will be in compliance, the agency will issue an aquifer exemption which allows mining within a defined portion of the uranium host aquifer.

20.4 Social or Community Impact

The Project is proximate to the communities of Jeffrey City, Casper, and Riverton. Jeffrey City is approximately 15 miles south of the Project and has an estimated population of 40 people (world population review, 2024). The Casper metropolitan area is approximately 60 miles east of the Project and has an estimated 2024 population of 79,941 people (world population review, 2024). Riverton is 40 miles from the site with an estimated population of 11,400 (world population review, 2024). enCore expects to hire site personnel from these communities as well as from other small communities in the region. Employment will likely have a positive impact on these communities not only through direct payroll, but through primary and secondary purchases of goods and services.

The immediate area around the facility is very sparsely populated. The nearest residence is approximately 10 miles from the Project. The next nearest residence is greater than 14 miles away.

A surety bond will be in place to ensure proper restoration and reclamation of the project. The surety will be updated annually during the life of the Project to account for changes in reclamation liability. Nuisance and hazardous conditions which could

Gas Hills Uranium Project Technical Report – February 2025 Page 85

affect local communities are not expected to be generated by the facility. The level of traffic in the region will increase slightly but impacts to local roads are expected to be minor. There are not expected to be agreements with the local communities, nor have any been requested.

20.5 Project Closure

20.5.1 Byproduct Disposal

The 11e.(2) or non-11e.(2) byproduct disposal methods are discussed in detail in Section 17. Deep disposal wells, landfills, and licensed 11e.(2) facilities will be used depending on waste classification and type.

20.5.2 Well Abandonment / Groundwater Restoration

Groundwater restoration will begin as soon as practicable after uranium recovery in each wellfield is completed. If a depleted wellfield is near an area that is being recovered, a portion of the depleted area’s restoration may be delayed to limit interference with on-going recovery operations. Groundwater restoration will require the circulation of native groundwater and extraction of mobilized ions through RO treatment. The intent of groundwater restoration is to return the groundwater quality parameters consistent with those established during the pre-operational sampling required for each wellfield. Restoration completion assumes up to three pore volumes of groundwater extracted and treated by reverse osmosis. Following completion of successful restoration activities and regulatory approval, the injection and recovery wells will be plugged and abandoned in accordance with WDEQ regulations. Monitor wells will also be abandoned following verification of successful groundwater restoration.

20.5.3 Demolition and Removal of Infrastructure

Simultaneous with well abandonment operations, the trunk and feeder pipelines will be removed, tested for radiological contamination, segregated as either solid 11e.(2) or non-11e.(2) byproduct material, then chipped on-site and disposed of on-site in appropriate disposal facilities. The header houses will be disconnected from their foundations, decontaminated, segregated as either solid 11e.(2) or non-11e.(2) by product material, and disposed of in appropriate disposal facilities or recycled. The processing equipment and ancillary structures will be demolished, tested for radiological properties, segregated and either scrapped or disposed of in appropriate disposal facilities based on their radiological properties.

20.5.4 Site Grading and Revegetation

Following the removal of wellfield and plant infrastructure, site roads will be removed and the site will be re-graded to approximate pre-development contours and the stockpiled topsoil placed over disturbed areas. The disturbed areas will then be seeded.

Gas Hills Uranium Project Technical Report – February 2025 Page 86

20.6 Financial Assurance

Throughout the life of the mine enCore will be required to annually assess the reclamation liability and submit the estimate to WDEQ-URP, WDEQ-LQD, and BLM for review and approval. The Project will be secured for the estimated amount of total closure costs which include groundwater restoration, facility decommissioning and reclamation with a bond provided by a broker. For the purposes of this Report, it was assumed that the bond cost charged by the broker would be 3 percent of the surety amount until positive cash flow is achieved then reducing to a rate of 2 percent thereafter. The annual financial surety amount is based on the estimated amount of annual development that would require closure in the case of default by the owner assuming a 3^rd party were responsible for the restoration and reclamation. The costs for financial assurance are included in the economic analysis presented herein.

20.7 Adequacy of Current Plans

The QP has reviewed the current status of the Project and has noted that additional design/planning is necessary before mining can begin. In addition, several permits are still required in order to begin mining. At this time the QP has found nothing that would prevent enCore from obtaining the appropriate permits in order to move towards ISR mining operations. At this juncture the project is typical of early stage ISR mines with good prospects of moving towards production.

Gas Hills Uranium Project Technical Report – February 2025 Page 87

21.0 CAPITAL AND OPERATING COSTS

Capital Costs (CAPEX) and Operating Costs (OPEX) are based on the geological evaluation of the ISR amenable resource as described in Section 14.0 and the installation of conceptual production patterns, header houses, pipelines, powerlines, fences, roads, and other infrastructure to produce 80 percent of the resource as described in Section 16.3.1. This evaluation considers measured and indicated resources only and excludes inferred resources. Estimated costs for the Project are based primarily on costs for materials and services developed for the Dewey-Burdock Project (Graves and Cutler, 2019). Available costs for additional projects including Ur Energy’s Shirley Basin ISR Uranium Project (WWC, 2024) and Strata Energy’s (Strata) 2022 Definitive Feasibility Study of Ross & Kendrick Areas at Lance (WWC 2022) were also utilized in developing CAPEX and OPEX costs. As currently envisioned, enCore would install a CPP at the Project with a capacity of 4,400 gpm and 1 million lbs per year U₃O₈ production. This is similar in size to the planned CPP at the Dewey-Burdock facility. Planning, permitting, and design is much further advanced in the Dewey-Burdock facility, so the costs developed in the Dewey-Burdock PEA are generally reliable.

To help offset costs, enCore has some used equipment currently on standby including a dryer system, eluant tanks, elution columns, slurry tanks, RO units, and sand filters at their Texas facilities that can be utilized in this project. The 2019 Dewey-Burdock cost estimate for the full CPP was $41.4 Million dollars. The 2019 Dewey-Burdock estimate includes 15 miles of new powerline construction and a new substation which is significantly more than what will be required at the Project. The cost estimate also included nearly $5 million for the deep disposal well which is considered separately in this analysis. The 2019 Dewey-Burdock evaluation also considered additional sales tax which is not applicable in Wyoming. Adjusting the original Dewey-Burdock costs to account for changes in electrical powerline construction, sales tax reductions, deep disposal wells considered elsewhere, and then including a $3 million credit for the dryer and other equipment enCore currently has on standby results in a comparable CPP cost of $24.9 Million at the Project. After adjusting for inflation, 23% (CPI, 2024), the comparable cost for the Dewey-Burdock CPP is estimated at $30.6 Million.

Many aspects of the Project are similar to the Shirley Basin Project, including well depths, proximity to historic open pit uranium mines, and location (the Shirley Basin Project is only 80 miles east/southeast of the Project). As with the Dewey-Burdock Project, design and planning for the Shirley Basin Project is also further advanced with reliable costs. Costs and capital purchases were escalated against either the Consumer Price Index (CPI, 2024) or the gross domestic product: implicit price deflator (FRED, 2024) adjusted to 2024 dollars. OPEX costs include all operating costs such as chemicals, labor, utilities and maintenance for the wellfield and the CPP. OPEX costs are most sensitive to wellfield operation costs which may increase if well spacing needs to be reduced or additional injection/production wells are required. In addition, increasing costs of materials, chemicals, and resin transportation costs could also lead to increased OPEX costs.

Gas Hills Uranium Project Technical Report – February 2025 Page 88

21.1 Capital Cost Estimation (CAPEX)

CAPEX costs were developed based on the current designs, quantities, and unit costs. The cost estimates presented herein are based on personnel and capital equipment requirements, as well as wellfield layouts, process flow diagrams, tank and process equipment and buildings at enCore’s Dewey-Burdock Project in western South Dakota as well as other similar uranium projects identified by the Authors. The Project has pre-mining development and capital costs of $55.2 million, which are detailed on Table 21.1.

After the start of mining, the CAPEX category will include subsequent mine unit drilling and wellfield installation costs as well as construction of transfer pipelines to move water from the Jeep, South Black Mountain, and Central Units to the CPP location in the West Unit. Wellfield development costs used in this analysis were developed based on costs estimated in the Shirley Basin 2024 PEA. The average well depth in the Project is nearly 60 ft. deeper than the average well in the Shirley Basin Project and the monitor wells will target the underlying rather than an overlying aquifer. As such, the costs were escalated to account for these factors. No additional contingency was applied to the CAPEX costs for the purposes of this report.

As discussed in Section 16.0, the first series of header houses will be brought online sequentially until the planned plant throughput (approximately 2,400 gpm) is attained. In the event headgrades at the plant fall below projected values, the CPP as considered in this analysis will have additional capacity (up to 4,400 gpm) to allow for flows to be increased to meet the production target of 1 million pounds of U₃O₈ per year. The remainder of the additional mine units will be developed in such a way as to allow for plant capacity/production targets to be maintained.

The wellfield development costs include both wellfield drilling and wellfield construction activities and were estimated based on the assumption that the wellfields in this Project will be similar in design to those in the Shirley Basin PEA (WWC, 2024). The wellfield costs include wells, header houses, and the hydraulic conveyance (piping) system associated with the wellfields. Additionally, trunk and feeder pipelines, electrical service, roads and wellfield fencing are included in the costs.

The accuracy of the CAPEX estimation complies with item 1302 of Regulation S-K for an Initial Assessment with economics.

Gas Hills Uranium Project Technical Report – February 2025 Page 89

Table 21.1. CAPEX Cost Summary

CAPEX Costs			Year -4				Year -3				Year -2				Year -1				Year 1				Year 2				Year 3				Year 4				Year 5				Year 6				Year 7				Year 8				Year 9				Year 10				Year 11				Totals				$/lb
			($000s except cost per pound data)
CPP Design and permitting		$	(500.0	)		$	(1,000.0	)		$	(1,000.0	)		$	–			$	–			$	–			$	–			$	–			$	–			$	–			$	–			$	–			$	–			$	–			$	–			$	(2,500.0	)		$	(0.41	)
CPP Construction		$	–			$	–			$	(8,000.0	)		$	(22,590.0	)		$	–			$	–			$	–			$	–			$	–			$	–			$	–			$	–			$	–			$	–			$	–			$	(30,590.0	)		$	(4.96	)
Disposal wells		$	–			$	–			$	(250.0	)		$	(4,750.0	)		$	–			$	–			$	–			$	–			$	–			$	–			$	–			$	–			$	–			$	–			$	–			$	(5,000.0	)		$	(0.81	)
Transfer Pipelines		$	–			$	–			$	–			$	–			$	–			$	–			$	(3,480.0	)		$	(2,320.0	)		$	(1,160.0	)		$	–			$	–			$	–			$	–			$	–			$	–			$	(6,960.0	)		$	(1.13	)
Wellfields		$	–			$	–			$	(5,832.3	)		$	(8,165.2	)		$	(11,664.5	)		$	(11,664.5	)		$	(11,664.5	)		$	(11,795.6	)		$	(11,244.6	)		$	–			$	–			$	–			$	–			$	–			$	–			$	(72,031.2	)		$	(11.69	)
Permitting, Claim Maintenance, and Administrative (G&A)		$	(596.6	)		$	(571.6	)		$	(962.6	)		$	(963.2	)		$	–			$	–			$	–			$	–			$	–			$	–			$	–			$	–			$	–			$	–			$	–			$	(3,094.0	)		$	(0.50	)
Total		$	(1,096.6	)		$	(1,571.6	)		$	(16,044.9	)		$	(36,468.4	)		$	(11,664.5	)		$	(11,664.5	)		$	(15,144.5	)		$	(14,115.6	)		$	(12,404.6	)		$	–			$	–			$	–			$	–			$	–			$	–			$	(120,175.2	)		$	(19.50	)

Notes:

1. CPP costs are based on similar sized facility at Dewey-Burdock.

2. Disposal well costs assume only one disposal well will be necessary.

3. Includes costs for large diameter pipelines to transfer fluids between mine units. Pipelines incidental to the wellfield are included in wellfield construction costs.

4. Wellfield costs include all costs and equipment required to drill wells, install pipelines, header houses, etc.

5. G&A costs only included during pre-production period. After production starts, costs are considered operational costs.

Gas Hills Uranium Project Technical Report – February 2025 Page 90

21.2 Operating Cost Estimation (OPEX)

The OPEX costs have been developed by evaluating and including each process unit operation and the associated required services (power, water, air, waste disposal), infrastructure (offices, shops and roads), salary and benefit burden, and environmental control (heat, air conditioning, monitoring). The annual OPEX and closure cost summary for the plant is provided in Table 21.2. Total OPEX costs, including selling, production and operating costs have been estimated at $95.6 million, or approximately $15.51 per pound. The costs are based on enCore’s estimated costs at the Dewey-Burdock Project (Graves and Cutler, 2019) and have no additional contingency attached except for escalation for inflation. The prices for the major items identified in this report have been sourced in the United States. Major cost categories considered when developing OPEX costs include wellfield, plant, processing, and site administration costs as detailed in Table 21.2.

The accuracy of the OPEX estimation complies with item 1302 of Regulation S-K for an Initial Assessment with economics.

Gas Hills Uranium Project Technical Report – February 2025 Page 91

Table 21.2. Annual Operating Costs (OPEX) Summary

Life of Mine Operating costs			Year -4				Year -3				Year -2				Year -1				Year 1				Year 2				Year 3				Year 4				Year 5				Year 6				Year 7				Year 8				Year 9				Year 10				Year 11				Totals				$/lb
			($000s except cost per pound data)
CPP, Disposal wells, Overflow pond		$	–			$	–			$	–			$	–			$	(4,902.8	)		$	(6,864.0	)		$	(9,805.7	)		$	(9,805.7	)		$	(9,805.7	)		$	(9,805.7	)		$	(9,452.7	)		$	–			$	–			$	–			$	–			$	(60,442.3	)		$	(9.81	)
Well Field Operation		$	–			$	–			$	–			$	–			$	(991.8	)		$	(1,388.5	)		$	(1,983.6	)		$	(1,983.6	)		$	(1,983.6	)		$	(1,983.6	)		$	(1,912.2	)		$	–			$	–			$	–			$	–			$	(12,226.9	)		$	(1.98	)
Aquifer Restoration and Decommissioning.		$	–			$	–			$	–			$	–			$	–			$	–			$	–			$	–			$	(1,522.6	)		$	(2,039.6	)		$	(2,039.6	)		$	(1,779.1	)		$	(777.5	)		$	(1,441.9	)		$	(556.0	)		$	(10,156.3	)		$	(1.65	)
U3O8 Conversion and Shipping fees		$	–			$	–			$	–			$	–			$	(205.0	)		$	(287.0	)		$	(410.0	)		$	(410.0	)		$	(410.0	)		$	(410.0	)		$	(395.2	)		$	–			$	–			$	–			$	–			$	(2,527.2	)		$	(0.41	)
Permitting, Claim Maintenance, and Administrative (G&A)		$	–			$	–			$	–			$	–			$	(824.9	)		$	(824.6	)		$	(824.6	)		$	(824.6	)		$	(824.6	)		$	(837.7	)		$	(831.9	)		$	(831.9	)		$	(889.9	)		$	(889.9	)		$	(897.2	)		$	(9,301.8	)		$	(1.51	)
Reclamation Bonding Surity Costs		$	–			$	–			$	–			$	(39.4	)		$	(51.3	)		$	(78.9	)		$	(109.9	)		$	(139.1	)		$	(136.6	)		$	(115.7	)		$	(89.7	)		$	(83.6	)		$	(62.8	)		$	(35.1	)		$	–			$	(942.1	)		$	(0.16	)
Bond collatoral		$	–			$	–			$	–			$	(460.2	)		$	(181.3	)		$	(345.2	)		$	(386.7	)		$	(365.1	)		$	30.7			$	261.7			$	325.2			$	423.8			$	173.4			$	231.0			$	292.5			$	0.0			$	0.00
Total		$	–			$	–			$	–			$	(499.6	)		$	(7,157.1	)		$	(9,788.2	)		$	(13,520.5	)		$	(13,528.1	)		$	(14,652.4	)		$	(14,930.6	)		$	(14,396.1	)		$	(2,270.8	)		$	(1,556.8	)		$	(2,135.9	)		$	(1,160.7	)		$	(95,596.6	)		$	(15.51	)

Notes:

1.CPP, Disposal wells, and Overflow Pond costs include power, labor, maintenance, chemicals and other costs associated with operation of the facilities.

2. Wellfield operation costs include labor, equipment, power, maintenance, chemicals and other wellfield operation costs.

3. Decommissioning costs assume no salvage value for materials and equipment.

4. Conversion and shipping fees assume shipments from Gas Hills CPP to conversion facility in Metropolis, Illinois

5. Reclamation bonding surety costs assume a 3% premium on the bond estimate prior to positive cashflow and 2% premium after positive cashflow.

6. Bond collateral assumed to be equal to 35% of the bond estimate prior to positive cashflow and then 25% of the bond estimate after positive cashflow.

Gas Hills Uranium Project Technical Report – February 2025 Page 92

22.0 ECONOMIC ANALYSIS

Cautionary statement: Mineral resources that are not mineral reserves do not have demonstrated economic viability. The estimated mineral recovery used in this Report is based on site-specific laboratory recovery data as well as enCore personnel and industry experience at similar facilities. There can be no assurance that recovery of the mineral resources at this level will be achieved. There is no certainty that the Preliminary Economic Assessment will be realized.

This Economic Analysis is based on the measured and indicated mineral resource and does not include any portion of the inferred mineral resource.

22.1 Assumptions

The economic assessment presented in this Report is based on geological evaluation and mapping of production areas, determining which areas are not viable for production activities due to hydrologic features, and obtaining an 80 percent recovery of the remaining resources, as described in Section 16.3.1.

A cash flow statement has been developed based on the CAPEX, OPEX, and closure cost estimates and the production schedule. As noted in Section 19, the sales price for the produced uranium is assumed at $87.00 per pound for the life of the Project. Sensitivities to uranium price are discussed in Section 25.2.

The production rate assumes an average solution uranium grade (headgrade) of approximately 97 mg/L. The sales for the cash flow are developed by applying the recovery factor to the Project resource estimate. The total uranium production over the life of the Project is estimated to be 6.16 million lbs.

22.2 Cash Flow Forecast and Production Schedule

The production estimates and OPEX distribution used to develop the cash flow are based on the production and restoration models developed by enCore and incorporated in the cash flow (Table 22.1). The cash flow assumes no escalation, no debt interest, or capital repayment. It also does not include depreciation. Estimated payback in the post-federal tax cash flow model is near the middle of the third year of production. Net cash flow before income tax over life of the Project is estimated to be $286.0 million and the net after-tax cash flow is estimated at $245.7 million. The Project has an estimated pre-tax Internal Rate of Return (IRR) of 54.8 percent and a Net Present Value (NPV) of $166.9 million. After-tax IRR and NPV are estimated at 50.2 percent and $141.8 million, respectively (Table 22.3). The NPV was calculated assuming an 8 percent discount rate. The NPV assumes cash flows take place in the middle of each period. NPV and IRR calculations are based on Year-2 through Year 11 and includes costs escalated by 8 percent per year from Year -4 and Year -3 treated as if the escalated costs occurred in Year-2. This approach to calculating the IRR and NPV was taken because Year -2 is the first year a significant sum of capital is invested in the project. Pre-income tax estimated cost of uranium produced is $40.61 per pound including royalties, severance

Gas Hills Uranium Project Technical Report – February 2025 Page 93

taxes, ad valorem taxes, plus all operating and capital costs. The IRR as well as pre-tax and post-tax NPV for three discount rates is presented in Table 22.2.

Gas Hills Uranium Project Technical Report – February 2025 Page 94

Table 22.1. Cash Flow Statement

Description		Units		Year -4				Year -3				Year -2				Year -1				Year 1				Year 2				Year 3				Year 4				Year 5				Year 6				Year 7				Year 8				Year 9				Year 10				Year 11				Totals				$/lb
Uranium Production as U3O8		lbs 000s			0				0				0				0				500				700				1000				1000				1000				1000				964				0				0				0				0				6164
Uranium Price for U3O8		US$/lb																		$	87			$	87			$	87			$	87			$	87			$	87			$	87
Uranium Gross Revenue		US$000s		$	–			$	–			$	–			$	–			$	43,500			$	60,900			$	87,000			$	87,000			$	87,000			$	87,000			$	83,868			$	–			$	–			$	–			$	–			$	536,268			$	87.00
Royalty (0.7%/year LOM average)		US$000s		$	–			$	–			$	–			$	–			$	(74.8	)		$	(104.3	)		$	(148.3	)		$	(148.3	)		$	(149.9	)		$	(150.3	)		$	(144.9	)		$	–			$	–			$	–			$	–			$	(920.8	)		$	(0.15	)
Net Sales Less Royalties		US$000s		$	–			$	–			$	–			$	–			$	43,425.2			$	60,795.7			$	86,851.7			$	86,851.7			$	86,850.1			$	86,849.7			$	83,723.1			$	–			$	–			$	–			$	–			$	535,347			$	86.85
State of Wyoming Severance Tax		US$000s		$	–			$	–			$	–			$	–			$	(953.5	)		$	(1,334.9	)		$	(1,907.0	)		$	(1,907.0	)		$	(1,907.0	)		$	(1,907.0	)		$	(1,838.4	)		$	–			$	–			$	–			$	–			$	(11,754.8	)		$	(1.91	)
County Ad Valorem Taxes		US$000s		$	–			$	–			$	–			$	–			$	(1,720.7	)		$	(2,409.0	)		$	(3,441.4	)		$	(3,441.4	)		$	(3,441.4	)		$	(3,441.4	)		$	(3,317.6	)		$	–			$	–			$	–			$	–			$	(21,212.9	)		$	(3.44	)
County Property Taxes		US$000s		$	–			$	–			$	–			$	–			$	(93.9	)		$	(84.5	)		$	(76.0	)		$	(68.4	)		$	(61.6	)		$	(55.4	)		$	(49.9	)		$	(44.9	)		$	(40.4	)		$	(36.4	)		$	(32.7	)		$	(644.1	)		$	(0.10	)
OPEX costs		US$000s		$	–			$	–			$	–			$	(499.6	)		$	(7,157.1	)		$	(9,788.2	)		$	(13,520.4	)		$	(13,528.0	)		$	(14,652.4	)		$	(14,930.5	)		$	(14,396.0	)		$	(2,270.8	)		$	(1,556.8	)		$	(2,135.9	)		$	(1,160.7	)		$	(95,596.4	)		$	(15.51	)
CAPEX costs		US$000s		$	(1,096.6	)		$	(1,571.6	)		$	(16,044.9	)		$	(36,468.3	)		$	(11,664.5	)		$	(11,664.5	)		$	(15,144.5	)		$	(14,115.6	)		$	(12,404.6	)		$	–			$	–			$	–			$	–			$	–			$	–			$	(120,175.1	)		$	(19.50	)
Subtotal OPEX, CAPEX, tax costs		US$000s		$	(1,096.6	)		$	(1,571.6	)		$	(16,044.9	)		$	(36,967.9	)		$	(21,589.7	)		$	(25,281.1	)		$	(34,089.3	)		$	(33,060.4	)		$	(32,467.0	)		$	(20,334.3	)		$	(19,601.9	)		$	(2,315.7	)		$	(1,597.2	)		$	(2,172.3	)		$	(1,193.4	)		$	(249,383.3	)		$	(40.46	)
Net Before U.S. Federal Income Cashflow		US$000s		$	(1,096.6	)		$	(1,571.6	)		$	(16,044.9	)		$	(36,967.9	)		$	21,835.5			$	35,514.6			$	52,762.4			$	53,791.3			$	54,383.1			$	66,515.4			$	64,121.2			$	(2,315.7	)		$	(1,597.2	)		$	(2,172.30	)		$	(1,193.40	)		$	285,963.90			$	46.39
Less Federal income tax		US$000s		$	–			$	–				$–			$	–			$	–			$	(3,882.26	)		$	(7,450.81	)		$	(7,280.00	)		$	(6,828.14	)		$	(7,123.78	)		$	(7,702.12	)		$	–			$	–			$	–			$	–			$	(40,267.1	)		$	(6.53	)
After Tax Cashflow		US$000s		$	(1,096.6	)		$	(1,571.6	)		$	(16,044.9	)		$	(36,967.9	)		$	21,835.5			$	31,632.3			$	45,311.6			$	46,511.3			$	47,555.0			$	59,391.6			$	56,419.1			$	(2,315.7	)		$	(1,597.2	)		$	(2,172.3	)		$	(1,193.4	)		$	245,696.8			$	39.86

Notes:

1) Production is based on an assumed 80% recovery of the measured and indicated resources described in Section 14. No Inferred resources are included.

2) Wyoming severance tax rate estimated at 4% of the taxable portion, see Section 22 for details.

3) Ad Valorem taxes are estimated at 7.2184% and 6.681% for Fremont and Natrona counties, respectively. The taxes are assessed on the taxable portion as described in Section 22.

4) See OPEX and CAPEX summary tables for details OPEX and CAPEX costs

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Table 22.2.  NPV Versus Discount Rate and IRR

Discount Rate		Pre-tax NPV ($US 000s)		Post-tax NPV ($US 000s)
5%		$203,626		$173,804
8%		$166,926		$141,778
10%		$146,396		$123,867
IRR		54.8%		50.2%

Note: NPV and IRR calculated from year -2. This is the first year significant sums of money are invested into the project.

22.3 Taxation

The current Wyoming severance tax for uranium is set on a sliding scale based on the current spot market price of uranium, below $30 per pound the severance tax rate is 0 percent, from $30.00 to $36.67 the tax rate is 1 percent, from $36.68 to $43.34 the tax rate is 2 percent, from $43.35 to $50.00 the tax rate is 3 percent, from $50.01 to $60.00 the tax rate is 4 percent, and at a spot price of more than $60.01 the tax rate is 5 percent. The sliding scale provision is scheduled to sunset in December 31, 2025. After December 31, 2025 the severance tax rate will be 4 percent regardless of the spot price. The severance tax rate at the Project for was calculated at 4 percent based on the assumption that no production will occur prior to 2026. Wyoming does not calculate the severance tax based on gross sales. Rather the valuation used to calculate the severance tax is reduced by an industry factor calculated by the state which takes into account the cost of production. In this Report, the industry factor was estimated at 54.8 percent.

Additionally, an ad valorem (gross products) tax is assessed at the county level on uranium sold. The ad valorem taxes are essentially a de facto property tax on production and are based on the mill levy in the jurisdiction of the mine. The ad valorem tax is 7.2184 percent in Fremont County and 6.681 percent in Natrona County. As with the severance tax, the ad valorem tax is not assessed on the gross sales but rather on a reduced valuation based on the same industry factor used for the severance tax calculations. In aggregate and based on the taxable portion of the product, the combined severance and ad valorem tax average approximately 6.5 percent of gross sales.

County property taxes will be assessed on mine improvements such as the CPP and buildings. Most of the project infrastructure will be in Fremont County. Fremont County will assess property taxes based on the value of the improvements. The assessed value of the mine improvements will be multiplied by an 11.5 percent valuation factor. The resulting valuation will then be multiplied by the mill levy (.072255) to calculate property taxes. The State of Wyoming has no corporate income tax.

At the federal level, profit from mining ventures is taxable at corporate income tax rates. For mineral properties, depletion tax credits are available on a cost or percentage basis, whichever is greater. To illustrate the potential impact of federal taxes, two economic models have been developed for this Report, one that includes an estimate of U.S. federal income tax and one that does not. It is important to note the

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estimate of U.S. federal income taxes included herein is not based on past operational history for this Project or this company and are strictly estimates at this time. For the purposes of this Report, the federal taxes were estimated at 21 percent of the taxable income. The taxable income was calculated by subtracting estimated depletion credits, depreciation, and carryforward loss deductions from the net cashflow. Only deductions from this Project were considered in the tax estimates and no other corporate losses or deductions were considered. It is possible that the tax liability presented herein is overstated because the tax estimate does not account for the potential offsetting tax deductions from other debts incurred in an overall corporate financial structure. This could be particularly true where other projects or expansions are likely to be funded from revenue from this project. The taxes calculated for this analysis are based on current tax laws and rates in 2024. Future changes to the U.S. tax code or the financial condition of the company will affect actual taxes paid during production.

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23.0 ADJACENT PROPERTIES

The Project is generally surrounded by mineral properties held by Cameco, Ur-Energy, Strathmore Uranium and others. However, all of the data used to evaluate the Project is from the Project and all of the mineral resources and mineral potential described herein lie entirely within the Project.

Over the past decade, Cameco has been observed conducting exploration drilling on their claims in the Gas Hills District and has permitted an ISR operation in the Gas Hills to extract uranium. Cameco has a Permit to Mine from the WDEQ-LQD (Permit #687) and a Source Materials License (SUA-1548) from the US Nuclear Regulatory Commission (NRC). The BLM completed a Final EIS in October 2013 and on February 13, 2014, announced a “Record of Decision” authorizing Cameco to proceed with development of their project using ISR techniques. Production was slated to begin in 2014 (Wyoming Business Report, February 22, 2011); however, due to a subsequent decline in spot uranium prices, Cameco has delayed their project. The Cameco property borders the Project on Cameco’s western, northeastern and southern extents. Table 23.1 summarizes the mineral resources for the Gas Hills Project from Cameco’s website (Cameco, 2023).

Table 23.1.  Cameco Peach Project Mineral Resources

Classification		Tonnes (x1000)		Grade % eU3O8		Pounds
Measured Resource		687.2		0.11		1,700,000
Indicated Resource		3,626.1		0.15		11,600,000
Inferred Resource		3,307.5		0.08		6,000,000

Sources: Cameco, 2023

It should be noted that the Authors have not verified the information on Cameco’s properties and the information may not be indicative of the mineralization that is present on the Project.

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24.0 OTHER RELEVANT DATA AND INFORMATION

To the Authors’ knowledge there is no additional information or explanation necessary to make this Report understandable and not misleading.

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25.0 INTERPRETATIONS AND CONCLUSIONS

This independent Report for the Project has been prepared in accordance with the guidelines set forth in NI 43-101 and regulations provided in SEC S-K 1300. Its objective is to disclose the potential viability of ISR operations at the Project.

25.1 Conclusions

The Authors have weighed the potential benefits and risks presented in this report and have found the Project to be potentially viable and meriting further evaluation and development.

25.2 Sensitivity Analysis

A sensitivity analysis was developed to evaluate the sensitivity of the NPV and IRR to changes in uranium prices. Both the pre-federal income tax and the post-federal income tax cashflow models were evaluated. Figure 25.1 shows pre-federal income tax sensitivity to changes in uranium prices and Figure 25.2 shows the post-federal income tax price sensitivity.

Figure 25.1. Pre-Federal Income Tax NPV and IRR Sensitivity to Price

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Figure 25.2. Post-Federal Income Tax NPV Sensitivity to Price

The Project is sensitive to changes in the price of uranium. Assuming an 8 percent discount rate, a $5.00 per pound change in the uranium price adjusts the pre-federal income tax NPV by just over $18 million and the post-federal tax NPV by just over $15 million. A $5.00 per pound increase in uranium price adjusts the pre-tax and post-tax IRR by approximately 3 percent.

Assuming an 8 percent discount rate and a constant uranium price of $87.00 per pound of U₃O₈, CAPEX and OPEX costs were varied in both the pre- and post-federal income tax cashflow models to evaluate effects on NPV. Figure 25.3 shows effects of variable OPEX and CAPEX costs on the pre-federal tax NPV. Figure 25.4 shows post-federal tax NPV changes with respect to variable CAPEX and OPEX costs. The evaluation demonstrates the NPV and IRR is sensitive to changes in both CAPEX and OPEX costs. A 5 percent change in CAPEX and OPEX costs can impact the NPV by approximately $5.6 million and $2.6 million in the pretax cashflow model, respectively. The IRR is also affected by changes in CAPEX and OPEX costs. A 5 percent change in OPEX costs adjusts the IRR by approximately 2 percent in the pre-tax cashflow model. The IRR change with respect to CAPEX cost changes is less linear and a 5 percent decrease in the CAPEX increases the IRR by approximately 7.5 percent while a 5 percent increase in the CAPEX cost decreases the IRR by approximately 8.2 percent in the pre-tax cashflow model.

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Figure 25.3. Pre-Federal Income Tax NPV Sensitivity CAPEX and OPEX

Figure 25.4. Post-Federal Income Tax NPV Sensitivity CAPEX and OPEX

A 5 percent change in the OPEX and CAPEX costs can have an impact to the NPV of approximately $3.0 million and $5.7 million in both the pre- and post-tax cashflow models, respectively. The IRR is also affected by changes in OPEX and CAPEX costs. The

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changes in IRR are not linear. A 5 percent change in the OPEX costs adjusts the IRR between 0.51 and 0.55 percent in both the pre- and post-tax cashflow models. The IRR change with respect to CAPEX cost adjustments is more non-linear and a 5 percent change in the CAPEX adjusts the IRR from 1.7 percent to 3.7 percent in both the pre- and post-tax cashflow models.

25.3 Risk Assessment

25.3.1 Resource and Recovery

It should be noted that recovery is based on both site-specific laboratory recovery data as well as the experience of enCore personnel and other industry experts at similar facilities. This Report is preliminary in nature and includes mineral resources which may not be recoverable at the rates indicated herein.

This Report is based on the assumptions and information presented herein. The QPs can provide no assurance that recovery of the resources presented herein will be achieved. Bench-scale tests have been performed on various core samples from the Project, as discussed in Section 13.0. The most significant potential risks to meeting the production results presented in this Report will be associated with the success of the wellfield operation and recovery of uranium from the targeted host sands. The estimated quantity of recovered uranium used in this Report is based primarily on the recovery data from site-specific, bench-scale testing of mineralized samples. The recovery factor of 80 percent, used herein, is relatively typical of industry experience for wellfield recovery. A potential problem that could occur in the wellfield recovery process is unknown or variable geochemical conditions resulting in uranium recovery rates from the mineralized zones that are significantly different from previous bench-scale tests.

This Report assumes acid consumption rates will average 55 lb/ton based on bottle roll tests discussed in Section 13.0. If actual acid consumption rates are higher than 55 lb/ton, this could negatively affect project economics.

This Report assumes an average headgrade of 97 ppm. If the average headgrade is less than 97 ppm, flowrates would have to be increased by bringing on additional patterns, header houses or mine units as necessary. In addition, the mining period will have to be extended in each wellfield to account for slower recovery rates. This scenario will increase both OPEX and CAPEX costs. To partially account for this potential risk, the CPP has extra capacity to accept higher flows which will help in the event headgrades are lower than anticipated.

This Report assumes three pore volumes of groundwater will be extracted and treated by reverse osmosis during restoration of the wellfields. There is a risk that more than three pore volumes of treatment will be required during restoration which may increase aquifer restoration costs.

The hydrologic conditions in the South Black Mountain area and Jeep area are largely unknown. There is a risk that unknown conditions such as faults, low hydraulic conductivities, or lower than anticipated water levels could limit ISR mining in these

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areas. Additional hydraulic studies in these areas would help minimize the potential risk of unknown conditions in these areas.

Faults, such as the Sagebrush fault identified within the Central Unit, have been noted adjacent to some of the resources included in this Report. There is the potential that inconsistent aquifer conditions near these features may limit recovery of the resources immediately adjacent to the faults.

Other potential concerns are reduced hydraulic conductivity in the formation due to chemical precipitation during production, lower natural hydraulic conductivities than estimated, high flare and/or recovery of significant amounts of groundwater, the need for additional injection wells to increase uranium recovery rates, variability in the uranium concentration in the host sands and discontinuity of the mineralized zone confining layers. The risks associated with these potential issues can be minimized to the extent possible by extensive delineation and hydraulic studies of the site which will occur during wellfield development.

The historic drill holes discussed in Section 16.2.2 present a small risk of connection between the mineralized aquifer and the underlying aquifer. There is a possibility an additional aquifer may overlie the ore bearing aquifer within the South Black Mountain area. It was assumed for the purposes of this Report there is no overlying aquifer to protect at South Black Mountain. In the event further analysis demonstrates there is an overlying aquifer, there is a risk that open boreholes could allow water to migrate into the overlying aquifer. This risk will be evaluated through the required aquifer pump tests that would likely show the presence of any excursion pathway when permitting mine units. Any historic boreholes that present a problem would need to be located and abandoned or mining operations will need to be modified to ensure overlying or underlying aquifers are not impacted. No costs for borehole abandonment were included in this Report.

The resources in the South Black Mountain area are significantly deeper than the resources in the other three areas. While the average well depth used for this Report factored in the deeper South Black Mountain wells, there will be a noticeable increase in wellfield costs for recovery of the South Black Mountain resources as compared to the other areas.

Some of the resources are near historic open pits where previous mining has occurred. The steep terrain presented by these open pits may be problematic for installation of perimeter monitor wells and wellfield patterns which may potentially limit resources that can be placed under pattern.

The pipelines that connect the resource areas to the CPP must cross land that is not controlled by enCore, there is risk that this will result in additional costs to analyze and acquire permits. Pipeline lengths in this analysis assume the pipelines will be relatively straight. Right of way negotiations may result in longer pipeline lengths which could increase the pipeline costs.

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Adequate disposal capacity for wastewater is always a risk when planning a uranium ISR facility. However, Cameco has applied for and obtained permit authorization from WDEQ to install deep disposal wells associated with their Gas Hills ISR Project (WDEQ, 2014). Cameco’s authorization allows for installation of up to three DDW’s which are located between 0.25 and 5.00 miles of the Central Unit. The wells are authorized for a maximum flow rate of 150 gallons per minute. Assuming actual disposal capacities compare favorably with the capacities estimated in the Cameco’s permit, DDW capacity will not be considered a risk to Project economics.

25.3.2 Markets and Contracts

The marketability of uranium and acceptance of uranium mining are subject to numerous factors beyond the control of enCore. History has shown that the price of uranium can experience volatile and significant price movements over short periods of time. Factors known to affect the market and the price of uranium include economic viability of nuclear power; political and economic conditions in uranium mining, producing and consuming countries; costs; interest rates, inflation and currency exchange fluctuations; governmental regulations; availability of financing of nuclear plants, reprocessing of spent fuel and the re-enrichment of depleted uranium tails or waste; sales of excess civilian and military inventories (including from the dismantling of nuclear weapons) by governments and industry participants; production levels and costs of production in certain geographical areas such as Asia, Africa and Australia; and changes in public acceptance of nuclear power generation as a result of any future accidents or terrorism at nuclear facilities.

Unlike other commodities, uranium does not trade on an open market. Contracts are negotiated privately by buyers and sellers. Changes in the price of uranium can have a significant impact on the economic performance of the Project. As discussed in Section 25.2, a $5.00 change in the spot commodity price results in a $20 million change to the pre-federal tax NPV at a discount rate of 8 percent. This Report assumes U₃O₈ production is sold at $87.00 per pound for the life of the Project. This price is based on a combination of projections from expert market analysts at institutions as noted in Section 19.0. There is a risk that uranium prices will be lower than the market analysts predict which would negatively affect the economics of this project.

25.3.3 Operations

Some operational risks such as reagents, power, labor and/or material cost fluctuations due to inflation, increasing demand, decreasing supply, or other market forces exist and could impact the OPEX and Project economic performance. These potential risks are generally considered to be addressable either though wellfield modifications or plant optimization.

Bonding costs and required collateral have been estimated in this Report based on costs encountered by other companies on reasonably sound financial footing. Bonding costs and/or collateral required as part of the bonding effort may increase for a number of reasons including poor performance in the future by enCore; uncertainty in market

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conditions; volatility in uranium prices; and changes in bonding practices implemented by the regulatory authorities.

ISR mining is occurring at other ISR facilities in Wyoming and Texas. The process does not use any unusual methods and the reagents for the process are readily available from regional sources. Initial process optimization will be required to minimize the use of reagents, minimize loss of product and ensure proper product quality.

Health and safety programs will be implemented to control the risk of on-site and off-site exposures to uranium, operational incidents and/or process chemicals. Standard industry practices exist for this type of operation and novel approaches to risk control and management will not be required.

This analysis minimizes fixed operational costs by assuming a relatively short duration and constant production rate. If the production rate is lower than estimated in this Report, the OPEX costs will be increased.

Minimal wellfield design or layout has been completed for this project. Wellfield costs have been estimated based on similar projects. There is a chance that wellfield costs could vary due to well spacing, monitor well location constraints or other factors not yet considered. As this project advances, increasingly detailed wellfield design will improve wellfield cost estimates.

The CPP location, DDW location, pipeline alignments and other facilities have been placed on the map for pre-planning purposes. No engineering studies or right-of-way agreements have been completed to ensure that the locations are adequate. Costs are based on costs encountered at other sites and do not consider unique conditions at the Project. Additional design will be required to verify the costs presented in this Report.

CPP construction costs have been estimated primarily by utilizing previous cost estimates at the Dewey-Burdock facility. Since the costs were developed, the United States has experienced much higher than normal inflation. Official inflationary rate factors developed by the Federal government were applied to develop cost estimates. However, there is a risk that inflationary pressures specific to the uranium ISR industry may vary from national averages resulting in higher costs.

25.3.4 Permitting

The WDEQ-LQD and BLM will be the key regulatory authorities of the Project. This Report assumes the project will be permitted with low pH recovery, which is typical of mining operations around the world, including the United States, where uranium ISR mines have operated using low pH lixiviant since the early 1960’s. In 2019, Peninsula Energy, Ltd. amended the Ross ISR Project source and byproduct license along with Permit to Mine No. 802 to include low pH recovery. This has provided the WDEQ-LQD with familiarity and comfort level with low pH recovery methods as a recovery option. Low pH field test operations were initiated at the Ross ISR Project in 2018 (Peninsula Energy, 2019). Established uranium ISR using low pH recovery methods in the state of

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Wyoming minimizes the risk that low pH recovery will require significant additional regulatory expense.

A large portion of the Project lies on BLM managed surface. Any development on federal land of this magnitude will require an approved plan of operations from the BLM and associated NEPA analysis. The BLM will be the primary lead federal agency for the NEPA analysis. This Report assumes that the BLM will require only an EA level of impact analysis in support of the approval process. However, there is a possibility that the BLM may require a more robust EIS. If the BLM evaluation requires the more robust EIS level of analysis, the pre-production permitting costs increase. Development of an EIS may increase the review and approval time as well though this cost was not addressed herein.

Certain areas of the Project are located immediately adjacent to areas designated by the Wyoming Game and Fish Department as a core sage grouse habitat. The West Unit and Central Unit lie wholly outside of the sage grouse core area whereas portions of Jeep and South Black Mountain lie within the sage grouse core area (Wyoming Game and Fish, 2024). The regulatory agencies may place stipulations or limitations on the portions of the Project that are within the sage grouse core area. The limitations may result in timing stipulations associated with some surface disturbance. Timing stipulations have the potential to increase OPEX costs.

25.3.5 Social and/or Political

As with any uranium project in the USA, there will undoubtedly be some social/political/environmental opposition to development of the Project. The Gas Hills is relatively remote and there are no residences within the immediate vicinity of the project. As such, there are very few people that could be directly impacted by the Project. In addition, the Gas Hills is the site of extensive historical uranium mining with significant long-term impacts. Wyoming is known to be friendly to mining which will help with permitting. The relative success of other similar ISR projects to obtain permits to operate in Wyoming indicates that, while it is ever present, social, political, or environmental opposition to the Project is not likely to be a major risk.

The Federal income taxes estimated in this analysis are based on tax codes and rates in 2024. The federal tax code is subject to change. Changes in the tax code could negatively affect the project economics.

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26.0 RECOMMENDATIONS

The QPs find the Project is potentially viable based on the assumptions contained herein. The Project is located in an area of extensive historical mining and the scale and quality of the ISR mineral resources indicate favorable conditions for future extraction from the Project. There is no certainty that the mineral recovery or the economic analyses presented in this Report will be realized. In order to realize the full potential benefits described in this Report, the following activities are recommended, at a minimum.

• Complete all activities required to obtain necessary licenses and permits required to operate an in-situ uranium mine in the Gas Hills of Wyoming. The approximate cost for this is $2.5 million and is included in the cash flow statement as a regulatory cost.

• Confirm hydrogeologic conditions are suitable for ISR operations within the Jeep and South Black Mountain Units. Aquifer testing at Jeep and South Black Mountain has been included in the regulatory costs above since this work would be necessary for mine planning purposes in addition to supporting licensing.

• Complete additional metallurgical testing to further verify and confirm the headgrade, estimated acid usage, lixiviant composition, and overall resource recovery used in this analysis is appropriate. This work should also evaluate and help identify approaches to avoid potential operational issues such as gypsum precipitation and restorability of the groundwater. Estimated costs for this work is $300,000.

• Due to the lack of current data on alternative lixiviants and consistent with enCore’s significant experience utilizing alkaline based lixiviants at their projects, the Authors recommend completing additional metallurgical studies and leach testing utilizing an alkaline based lixiviant. This work could be included with the other metallurgical testing conducted to verify acid usage.

• As an alternative to constructing a full CPP at the site, enCore may consider a satellite IX plant at the Project and develop toll milling agreements with a processing facility to process loaded resin. Costs to develop agreements would be minimal and the cost of toll milling would be determined as part of the confidential agreement.

• Advance wellfield design to verify the assumptions included herein are appropriate and that all the pounds in this Report can be put under pattern. Approximate cost for the first stage of this would be $25,000. Subsequent stages of design would tier off the results of the initial stage of design.

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• Advance the CPP, pipeline, containment pond, and deep disposal well designs to permit level designs. Approximate cost for permit level designs and details are estimated at $200,000.

• Develop agreements for pipeline right-of-ways. Costs may vary depending on specific ownership and agreements but are initially estimated at $25,000.

• With favorable market conditions, conduct additional exploratory drilling to evaluate not fully explored mineral trends throughout the Project area. Approximate costs for a moderately scaled exploration drilling program are estimated at $200,000 and could be combined with a core drilling program to support additional metallurgical testing.

Gas Hills Uranium Project Technical Report – February 2025 Page 109

27.0 REFERENCES

American Nuclear Corporation, 1985, Gas Hills Mineral Inventory Report as of January 1, 1984, 422p, 2 plates (claim location map), February 5, 1985.

Anonymous, 1979, Gas Hills Uranium District, Day Loma/ROX claims, Exploration Progress Report, June 1979, 33 p.

Armstrong, F.C., 1970, Geologic factors controlling uranium resources in the Gas Hills district, Wyoming: Wyoming Geol. Assoc. 22^nd Annual Field Conf. Guidebook, p. 31-44.

Beahm, Douglas L. (BRS), 2017, Amended and Restated Gas Hills Uranium Project Mineral Resource and Exploration Target NI 43-101 Technical Report Fremont and Natrona Counties Wyoming, USA, June 9, 2017.

Cameco, 2023: Reserves & Resources as of December 31, 2023. Available on the internet as of January 2025 https://www.cameco.com/sites/default/files/documents/2023-mineral-reserves-and-resources.pdf

Carbon Credits.com, 2025 Uranium Outlook: Will this Critical Commodity Endure its Golden Glow? Article prepared by Saptakee S. January 3,2025. https://carboncredits.com/2025-uranium-outlook-will-this-critical-commodity-endure-its-golden-glow/

Century Geophysical Corporation, 1975, Jerry West, Uranium Logging Techniques, Logging Operator’s Manual Section III-A, August 26, 1975.

Century Wireline Services, 2017, Uranium Logging Technique Brochure.

CPI, 2024, Consumer price Index Data, online database accessed at https://www.usinflationcalculator.com/inflation/, available online as of January 2025.

Dames & Moore, 1976, Evaluation of four uranium claim groups in Wyoming for Adobe Oil & Gas Corporation: unpublished report, 39 p. plus appendices, Denver, Colorado.

David Robinson & Associates, Inc., 1979, Estimate of uranium reserves, Day Loma and Rox claims for Energy Fuels Nuclear, Inc., Sept 11, 1979, 13 p., 3 maps.

Davis, J.F., 1969, Uranium Deposits of the Powder River Basin, Wyoming Uranium Issue, Contr. Geology, v. 8, no. 2, pt. 1, p. 131-141.

De Voto, R.H., 1978, Uranium Geology and Exploration, Colorado School of Mines, Golden, Colorado, 400 p.

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Dodd, P. H., Droullard, R.F., and Lathan, C. P., 1967, Borehole Logging Methods for Exploration and Evaluation of Uranium deposits, US Atomic Energy Commission, Grand Junction, Colorado, in Mining and Groundwater Geophysics, p. 401-415.

Energy Fuels, Inc., 1978, Geology and ore reserve calculations of the Gas Hills properties, Wyoming: 50p., 10 plates, June 2, 1978.

Energy Fuels, Inc., 1979, Gas Hills Uranium District, Day Loma/ROX claims, Exploration Progress Report, 100 p., 15 plates (drill hole and resource estimate maps), June 1979.

Fred, 2024 Fred Online Economic Data, Online database located at: https://fred.stlouisfed.org/series/GDPDEF Accessed December 16, 2024.

Granger, H.C. and Warren, C.G., 1974, Zoning in the altered tongue associated with roll-type uranium deposits: International Atomic Energy Agency, Symposium uranium ore deposits, Athens, May 6-10, 1974.

Granger, H.C. and Warren, C.G., 1978, Some speculations on the genetic geochemistry and hydrology of roll-type uranium deposits: Wyoming Geol. Assoc. Guidebook, p. 341-361.

Graves, D.H and Cutler, 2019 S, NI 43-101 Technical Report Preliminary Economic Assessment Dewey-Burdock Uranium ISR Project South Dakota, USA, Prepared for Azarga Uranium, Effective Date December 3, 2019, Report Date January 17, 2020.

Gregory, R.W., 2019, Uranium Geology and Resources of the Gas Hills District, Wind River Basin, Central Wyoming: Wyoming State Geological Survey Public Information Circular No. 47, 31 p.

Harshman, E.N., 1962, Alteration as a guide to uranium ore, Shirley Basin, Wyoming, U.S.G.S. Prof. Paper 450-D, Article 122, p. D8-D10.

Hydro-Engineering, LLC, 2013, Appendix D6 Hydrogeology, from Strathmore Resources (USA) Ltd. Gas Hills Uranium Miner Permit Application, prepared for Strathmore Resources Ltd., August 2013.

Hydro-Engineering, LLC, 2018, Analysis of the Wind River Aquifer Water-Level Elevations in the Gas Hills, prepared for UColo Exploration Corp., April 2018.

Hydro-Engineering, LLC, 2018, Aquifer Analysis of the Wind River Aquifer Hydraulic Properties in the Gas Hills, prepared for UColo Exploration Corp., June 2018.

Hydro-Engineering, LLC, 2021, Modeling of the Potential ISR Mining at the George-Ver Mining Area, prepared for Azarga Uranium Corp., March 2021.

Gas Hills Uranium Project Technical Report – February 2025 Page 111

King, J.W. and Austin S.R, 1966, Some characteristics of roll-type uranium deposits at Gas Hills, Wyoming: Mining Engineers, no. 5, p.73-80.

McKay, A. D., Stoker, K. F., Bampton, K. F., Lambert, I. B., 2007, Resource estimates for In Situ Leach Uranium and Reporting Under the JORC Code, Bulletin, December 2007.

Lyntek, 2013 “Preliminary Metallurgical Testing Summary, Agitation Test Work – Report 1, Uranium Heap Leach, Gas Hills Project” prepared for Strathmore Minerals Corp.

Lyntek, 2013 “Preliminary Metallurgical Test Summary, Winter 2011, Column Leach Report” prepared for Strathmore Minerals Corp.

Lyntek, 2013 “Preliminary Metallurgical Test Summary – Summer 2012, Column Leach Test Report III, Uranium Heap Leach Gas Hills Project” prepared for Strathmore Minerals Corp.

Lyntek and Alexander, B., 2013, “Gas Hills Uranium Recovery Project, Metallurgical Investigations, Ion Exchange Testing” prepared for Strathmore Minerals Corp.

Michel, Tom, 2021 Gas Hills ISR Mining Potential, Internal Technical Memorandum prepared for Azarga, March 24, 2021.

Peninsula Energy, ltd, 2019, Successful Mining Phase Outcomes from Low pH Field Demonstration, Company Announcement, Available online at https://www.pel.net.au/projects/lance-projects-wyoming/project-updates/ , April 1 2019.

Roughstock and WWC, 2021, NI 43-101 Technical Report Preliminary Economic Assessment, Gas Hills Uranium Project, Fremont and Natrona Counties, Wyoming, USA. August 2021.

Seeland, D.A., 1978, Sedimentologic and Structural Controls of Uranium Deposits in the Tertiary Basins of Wyoming, Bendix Field Engineering Corp., Grand Junction, Colorado, p. 99, February 1978.

Sprott, 2024. Uranium Markets Impacted by Market Signals and Uncertainty, article prepared by Jacob White. December 13, 2024. https://sprott.com/insights/uranium-markets-impacted-by-market-signals-and-uncertainty/

Sprott, 2025. Interview with Sprott CEO John Ciampaglia, January 28, 2025. https://sprott.com/insights/uranium-outlook-for-2025/

Snow, C.D., 1978, Gas Hills uranium district, Wyoming—A review of history and production: 30^th Annual Conf., Wyoming Geol. Assoc. Guidebook p. 329-333.

Gas Hills Uranium Project Technical Report – February 2025 Page 112

Soister, P.E., 1968, Stratigraphy of the Wind River Formation in south-central Wind River Basin, Wyoming: U.S. Geological Survey Professional Paper 594-A, 50 p.

Strathmore Resources Ltd. (Strathmore), 2013. Strathmore Gas Hills Project Permit to Mine Appendix D-5 Geology.

Trade Tech, 2023. 4th Quarter 2023 Market Outlook Report. Proprietary Report Paid for and Acquired by Encore, https://www.uranium.info/uranium_market.php

US Climate Data, 2021: Casper Wyoming Climate Data. Available on the internet as of June 20211 https://www.usclimatedata.com/climate/casper/wyoming/united-states/uswy0030.

Van Houten, F.B., 1964, Tertiary Geology of the Beaver Rim Area, Fremont and Natrona Counties, Wyoming: U.S.G.S. Geological Survey Bulletin 1164, 99 p. ill., maps, United States Printing Office, Washington, D.C.

Woolery, R.G., Ramachandran, S., Hansen, D.J., and Weber, J.A., 1978, Heap Leaching of Uranium: A Case Study, Mining Engineering Journal, New York, v. 30(3), p. 285-290.

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Wyoming Department of Environmental Quality, 2014, Class 1 Injection Well Authorization Permit # 13-262 (UIC Facility number WYS-013-00116), issued February 5, 2014 to Cameco Resources (Gas Hills ISR Facility).

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APPENDIX A:

CERTIFICATE OF QUALIFIED PERSONS

Gas Hills Uranium Project Technical Report – February 2025 Page 114

CERTIFICATE OF QUALIFIED PERSON

Technical Report on the Gas Hills Uranium Project, Fremont and Natrona Counties,

Wyoming, USA

I, Christopher McDowell, Wyoming Professional Geologist, of 1849 Terra Avenue, Sheridan, Wyoming, do hereby certify that:

I have been retained by enCore Energy Corp., 101 N. Shoreline Blvd, Suite 450, Corpus Christi, TX 78401, to prepare and supervise the preparation of the documentation for the foregoing report “Technical Report on the Gas Hills Uranium Project, Fremont and Natrona Counties, Wyoming, USA” with an effective date of December 31, 2024 (the “Report”) to which this Certificate applies.

I am currently employed by WWC Engineering, 1849 Terra Avenue, Sheridan, Wyoming, USA, as a Professional Geologist.

I graduated with a Bachelor of Science degree in Geology in August 2016 and a Master of Business Administration degree in August 2022 both from the University of Wyoming in Laramie, Wyoming.

I am a licensed Professional Geologist in the State of Wyoming in good standing, license number 4135. I am a licensed Professional Geologist in the State of Texas in good standing, license number 15284. I am a Registered Member of the Society of Mining, Metallurgy and Exploration. My Registration Number is 4311521 and I am in good standing.

I have worked as a geologist for 9 years in natural resources extraction.

I have 9 years direct experience with uranium exploration, resource analysis, uranium ISR project development, project feasibility, permitting, and licensing. My relevant experience for the purposes of the Gas Hills Uranium Project includes roles as a geologist and project manager at WWC Engineering. My project experience includes, but is not limited to, preparing or assisting in the preparation of the NI 43-101 Technical Report on the Resources of the Moore Ranch Uranium Project, Campbell County, Wyoming, USA, April 30, 2019, the NI 43-101 Preliminary Economic Assessment Gas Hills Uranium Project Fremont and Natrona Counties, Wyoming, USA August 10, 2021, the NI 43-101 Preliminary Economic Assessment Shirley Basin ISR Uranium Project, Carbon County, Wyoming, USA, March 7, 2022 and March 11, 2024, the NI 43-101 Preliminary Economic Assessment Lost Creek Uranium Property Sweetwater County, Wyoming, USA March 7, 2022 and March 4, 2024, and acting as QP on the NI 43-101 Technical Report Kaycee Uranium Project Johnson County, WY USA dated September 6 2024.

Gas Hills Uranium Project Technical Report – February 2025 Page 115

I have read the definition of “qualified person” set out in NI 43-101 and S-K 1300 and certify that by reason of my education, professional registration, and relevant work experience, I fulfill the requirements to be a “qualified person”.

I visited the Gas Hills Uranium Project on May 24, 2021.

I am responsible for the preparation and/or supervision of the preparation of responsible for development of sections 1-15 and 23-27 of this Report.

I am independent of enCore Energy Corp. as described in Section 1.5 of NI 43-101.

I have read NI 43-101 and certify that this Technical Report has been prepared in compliance with NI 43-101.

To the best of my knowledge, information and belief, at the effective date of the Technical Report, the Technical Report contains all scientific and technical information that is required to be disclosed to make the Technical Report not misleading.

Dated this 4^th day of February 2025

Signed and Sealed:

/s/ Christopher McDowell

Christopher McDowell, P.G.

SME Registered Member, Registration Number 4311521

Professional Geologist, Texas No. 15284

Gas Hills Uranium Project Technical Report – February 2025 Page 116

CERTIFICATE OF QUALIFIED PERSON

Technical Report on the Gas Hills Uranium Project, Fremont and Natrona Counties,

Wyoming, USA

I, Ray B. Moores, Wyoming Professional Engineer, of 1849 Terra Avenue, Sheridan, Wyoming, do hereby certify that:

I have been retained by enCore Energy Corp., 101 N. Shoreline Blvd, Suite 450, Corpus Christi, TX 78401, to prepare and supervise the preparation of the documentation for the foregoing report “Technical Report on the Gas Hills Uranium Project, Fremont and Natrona Counties, Wyoming, USA” with an effective date of December 31, 2024 (the “Report”) to which this Certificate applies.

I am currently employed by WWC Engineering, 1849 Terra Avenue, Sheridan, Wyoming, USA, as a Civil Engineer/Project Manager.

I graduated with a Bachelor of Science degree in Civil Engineering in December 2000 and a Master of Science degree in Civil Engineering in May 2002 from the University of Wyoming in Laramie, Wyoming.

I am a licensed Professional Engineer in the State of Wyoming. My registration number is 10702 and I am a member in good standing.

I have worked as an engineer for 22 years primarily in support of natural resources extraction.

I have 16 years of direct experience with ISR uranium mining, permitting, groundwater modeling, and mine infrastructure design and construction. My relevant experience for the purposes of the Gas Hills Uranium Project includes development of a groundwater model for Strata Energy’s Ross ISR Uranium Project, which included wellfield scale simulations, well spacing evaluations, and restoration evaluations; providing technical assistance for a number of ISR uranium mine projects in Wyoming, South Dakota, Texas and New Mexico, which included aquifer analyses, ISR mining amenability evaluations, and infrastructure evaluations in support of due diligence studies; permit preparer for Strata Energy’s Ross ISR Uranium Project; providing engineering design, cost estimates, and project management for a number of dams, diversions, evaporation ponds, and other infrastructure associated with Wyoming coal mines and oil and gas projects; preparation of socioeconomic impact analyses for new coal mining projects in Wyoming and West Virginia, qualified person on the NI 43-101 Preliminary Economic Assessment of Anatolia Energy’s Temrezli ISR Project in Yozgat, Turkey; qualified person on NI 43-101 Preliminary Economic Assessment Shirley Basin Uranium Project in Carbon County Wyoming, dated January 27, 2015; qualified person on NI 43-101, Technical Report Preliminary Economic Assessment, Gas Hills Uranium Project, Fremont and Natrona Counties, WY, dated June 28, 2021, qualified person on NI 43-101 Preliminary Economic Assessment Lost Creek ISR Uranium Property, Sweetwater County, Wyoming, USA dated March 4, 2024, and qualified person on NI 43-101 Amended Preliminary Economic Assessment Shirley Basin ISR Uranium Project, Carbon County, Wyoming, USA dated March 11, 2024.

Gas Hills Uranium Project Technical Report – February 2025 Page 117

I have read the definition of “qualified person” set out in NI 43-101 and S-K 1300 and certify that by reason of my education, professional registration, and relevant work experience, I fulfill the requirements to be a “qualified person” for those purposes.

I visited the Gas Hills Uranium Project on May 24, 2021.

I am responsible for the preparation and/or supervision of sections 1-5, 16-22, and 24-27 of this Report

I am independent of enCore Energy Corp. as described in Section 1.5 of NI 43-101.

I have read NI 43-101 and certify that this Report has been prepared in compliance therewith.

To the best of my knowledge, information, and belief, at the effective date of this Report, December 31, 2024, the Report contains all scientific and technical information that is required to be disclosed to make the Report not misleading.

Dated this 4^th day of February 2025

Signed and Sealed:

/s/ Ray B. Moores

Ray B. Moores, P.E.,

Professional Engineer, Wyoming No. 10702

Gas Hills Uranium Project Technical Report – February 2025 Page 118

APPENDIX B:

LIST OF LODE CLAIMS AND STATE LEASES

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