EDGAR 10-K Filing

Company CIK: 1375205
Filing Year: 2025
Filename: 1375205_10-K_2025_0001558370-25-004728.json

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ITEM 1. BUSINESS
Items 1 and 2. BUSINESS AND PROPERTIES
Overview and Corporate Structure
Incorporated on March 22, 2004, we are engaged in uranium mining, recovery and processing activities, including the acquisition, exploration, development and operation of uranium mineral properties in the U.S. Through our Wyoming operating subsidiary, Lost Creek ISR, LLC, we began operation of our first in situ recovery uranium facility at our Lost Creek Project in 2013. Ur-Energy is a corporation continued under the Canada Business Corporations Act on August 8, 2006. Our Common Shares are listed on the NYSE American under the symbol “URG” and on the TSX under the symbol “URE.”
We announced our decision in December 2022 to immediately ramp up Lost Creek production to levels sufficient to deliver into our sales commitments. During 2023, we captured 103,487 pounds of U3O8 at our Lost Creek plant. We sold 280,000 pounds U3O8 in 2023 from existing inventory. These sales were our first sales of produced U3O8 since 2019. During 2024, we captured 265,746 pounds of U3O8 at our Lost Creek plant. We sold 570,000 pounds U3O8 in 2024 from our Lost Creek production and other sources of non-produced inventory.
We are an “exploration stage issuer,” as that term is defined under S-K 1300, because we have not established proven or probable mineral reserves through the completion of a pre-feasibility or feasibility study for any of our uranium projects. As a result, and even though we commenced recovery of uranium at our Lost Creek Project in 2013, we remain classified as an exploration stage issuer and will continue to remain an exploration stage issuer until such time as proven or probable mineral reserves have been established.
We are engaged in uranium recovery and processing operations, in addition to the exploration for and development of uranium mineral properties. Uranium fuels carbon-free, emission-free nuclear power which is a clean, cost-effective, and reliable form of electrical power. Nuclear power is estimated to provide more than 50 percent of the carbon-free electricity in the U.S. and approximately one-third of carbon-free electricity worldwide. As a uranium producer, we are advancing the interests of clean energy, thereby contributing in positive ways to address the challenges of global climate change.
Ur-Energy has one direct wholly owned subsidiary: Ur-Energy USA Inc. (“Ur-Energy USA”), a company incorporated under the laws of the State of Colorado. It has offices in Colorado and Wyoming and has employees in both states.
Ur-Energy USA has three wholly-owned subsidiaries: Lost Creek ISR, LLC, a limited liability company formed under the laws of the State of Wyoming to hold and operate our Lost Creek Project and certain other of our Lost Creek properties and assets; NFU Wyoming, LLC (“NFU Wyoming”), a limited liability company formed under the laws of the State of Wyoming which acts as our land holding and exploration entity; and Pathfinder Mines Corporation (“Pathfinder”), a company incorporated under the laws of the State of Delaware, which holds, among other assets, the Shirley Basin and Lucky Mc properties in Wyoming. Lost Creek ISR, LLC employs personnel at the Lost Creek Project and, currently, in our Casper construction shop and chemistry laboratory.
Currently, and at December 31, 2024, our principal direct and indirect subsidiaries, and affiliated entities, and the jurisdictions in which they were incorporated or organized, are as follows:
Our wholly owned Lost Creek Project in Sweetwater County, Wyoming is our flagship first property. The project has been fully permitted and licensed since October 2012. We received operational approval from the U.S. Nuclear Regulatory Commission (“NRC”) and started production operation activities in August 2013. Our first sales of Lost Creek production were made in December 2013.
From commencement of operations until 2020, we had multiple term uranium sales agreements in place with U.S. utilities for the sale of Lost Creek production or other yellowcake product at contracted pricing. We completed our initial sales contracts in 2020 when we sold 200,000 pounds of Uranium Oxide (“U3O8”). We did not make any sales of U3O8 inventory in 2021 - 2022.
We sold 100,000 pounds U3O8 to the U.S. Department of Energy (“DOE”) National Nuclear Security Administration (“NNSA”) in January 2023, as a part of the national uranium reserve program. In 2023, we delivered 180,000 pounds U3O8 into one of our sales agreements, for a total of 280,000 pounds U3O8 sold in 2023 for proceeds of $17.3 million. In 2024, we delivered 570,000 pounds U3O8 into two of our sales agreements for proceeds of $33.1 million.
Shirley Basin, our other material property, and second flagship property, is one of the assets we acquired as a part of the Pathfinder acquisition in 2013. We also acquired all the historic geologic and engineering data for the project. During 2014, we completed a drill program of a limited number of confirmatory holes to complete an NI 43-101 mineral resource estimate which was released in August 2014; subsequently, an NI 43-101 Preliminary Economic Assessment for Shirley Basin was completed in January 2015. See also “Shirley Basin ISR Uranium Project S-K 1300 Report,” below. Baseline studies necessary for the permitting and licensing of the project commenced in 2014 and were completed in 2015.
In December 2015, our applications for a permit and license to mine at Shirley Basin was submitted to the State of Wyoming Department of Environmental Quality (“WDEQ”). The Wyoming Uranium Recovery Program (“URP”) issued our source material license and the Land Quality Division (“LQD”) issued the permit to mine for Shirley Basin in 2021. We received approvals for the project from the U.S. Bureau of Land Management (“BLM”) in 2020. Therefore, all major authorizations to construct and operate at Shirley Basin have been received. We have begun construction and development at the site, with construction of the satellite plant planned in 2025. We anticipate production will begin at Shirley Basin in Q1 2026.
We currently have seven multi-year sales agreements for delivery of a base quantity ranging between 440,000 and 1,300,000 pounds U3O8 annually from 2025 through 2030. Our agreements also provide for smaller 100,000-pound annual deliveries in 2032 and 2033.
We utilize in situ recovery (“ISR”) of the uranium at Lost Creek and will do so at other projects where this is possible, including Shirley Basin. The ISR technique is employed in uranium extraction because it allows for a lower cost and effective recovery of roll front mineralization. The ISR technique does not require the installation of tailings facilities or significant surface disturbance. This recovery method utilizes injection wells to introduce a mining solution, called lixiviant, into the mineralized zone. The lixiviant is made of natural groundwater fortified with oxygen as an oxidizer, carbon dioxide for pH control, and may include the addition of sodium bicarbonate as a complexing agent. The complexing agent bonds with the uranium to form uranyl carbonate, which is highly soluble. The dissolved uranyl carbonate is then recovered through a series of production wells and piped to a processing plant where the uranyl carbonate is removed from the solution using ion exchange (“IX”) and captured on resin contained within the IX columns. The groundwater is re-fortified with the oxidizer and, possibly, the complexing agent and sent back to the wellfield to recover additional uranium. A small volume of water, called bleed, is permanently removed from the lixiviant flow to create an inward groundwater gradient. A reverse osmosis (“RO”) process is available to minimize the wastewater stream generated. Brine from the RO process, if used, and bleed are disposed of by means of injection into deep disposal wells. Each wellfield is made up of multiple groupings of injection and production wells installed in patterns to optimize the areal sweep of fluid through the uranium deposit.
Our Lost Creek processing facility includes all circuits for the capture, concentration, drying and packaging of uranium yellowcake for delivery into sales. Our processing facility, in addition to the IX circuit, includes processing trains with separate elution, precipitation, filter press and drying circuits (this contrasts with certain other uranium in situ recovery facilities which operate as a capture plant only, and rely on agreements with other producers for the finishing, drying and packaging of their yellowcake end-product). Additionally, a restoration circuit including an RO unit was installed during initial construction of Lost Creek to complete groundwater restoration once mining is complete.
We continue to make great strides in reducing water consumption. The first such achievement was the implementation of a Class V treatment system which became operational in 2017. The system includes water treatment and injection of the clean water into a shallow formation where it can be accessed by future generations. Since implementation of the Class V system, the generation of wastewater during production has been reduced significantly. To further reduce water consumption and enhance IX effectiveness, detailed design and engineering work is progressing for a filtration and wastewater treatment facility, together with procurement of equipment. Field construction will occur as appropriate as design work advances. The system, as envisioned, will allow for more effective use of current and future deep disposal wells working in conjunction with the Class V water recycling system while preserving precious water resources. Our goal is to further reduce wastewater generation by at least an additional 70 percent.
The elution circuit (the first step after IX) is utilized to transfer the uranium from the IX resin to elution tanks and concentrate the uranium to the point where it is ready for the next phase of processing. The resulting rich eluate is an aqueous solution containing uranyl carbonate, salt and sodium carbonate and/or sodium bicarbonate. The precipitation circuit follows the elution circuit and removes the carbonate from the concentrated uranium solution and combines the uranium with peroxide to create a yellowcake crystal slurry. Filtration and washing is the next step, in which the slurry is loaded into a filter press where excess contaminants such as chloride are removed and a large portion of the water is removed. The final stage occurs when the dewatered slurry is moved to a yellowcake dryer, which further reduces the moisture content, yielding the final dried, product. Refined, salable yellowcake is packaged in 55-gallon steel drums and transported by truck to the conversion facility.
The restoration circuit may be utilized in the production as well as the post-mining phases of the operation. The RO is utilized as a part of our Class V recycling circuit to minimize the wastewater stream generated during production. Once production is complete, the groundwater must be restored to its pre-mining water quality or to concentrations that support the pre-mining class of use. The first step of restoration involves removing a small portion of the groundwater and disposing of it (commonly known as groundwater sweep). Following sweep, the groundwater is treated utilizing RO and re-injecting the clean water. Finally, the groundwater is homogenized and sampled to ensure the cleanup is complete, concluding the restoration process.
Our Lost Creek processing plant was constructed beginning in 2012, with production operations commencing in August 2013. Following receipt of amendments to our source material license in 2021, the licensed capacity of our Lost Creek processing plant allows for up to 2.2 million pounds U3O8 per year, of which up to 1.2 million pounds U3O8 per year may be produced from Lost Creek wellfields. The Lost Creek plant and the allocation of resources to mine units and resource areas were designed to generate approximately one million pounds of production per year at certain flow rates and uranium concentrations subject to regulatory and license conditions. The excess capacity in the design of the processing circuits of the plant is intended, first, to facilitate routine (and non-routine) maintenance on any particular circuit without hindering production operational schedules. The capacity was also designed to allow us to process uranium from other mineral projects in proximity to Lost Creek if circumstances warrant in the future (e.g., Shirley Basin Project) or,
alternatively, to be able to contract to toll mill/process product from other uranium mine sites in the region. The design permits us to conduct either of these activities while Lost Creek is producing and processing uranium and/or in years following Lost Creek production from wellfields during final restoration activities.
We plan for the Lost Creek processing facility to be utilized for the drying and packaging of uranium from Shirley Basin, for which we are building only a satellite plant. However, the Shirley Basin license and permit allows for the construction of a full processing facility, providing greater construction and operating flexibility as future market conditions may suggest.
Our Mineral Properties
Below is a map showing our Wyoming projects and the geologic basins in which they are located.
Our current land portfolio in Wyoming includes 12 projects. Ten of these projects are in the Great Divide Basin (“GDB”), Wyoming, including our flagship project, Lost Creek Project. We control nearly 1,800 unpatented mining claims and three State of Wyoming mineral leases for a total of approximately 35,400 acres at our Lost Creek Property, including the Lost Creek permit area (the “Lost Creek Project” or “Lost Creek”) and certain adjoining projects which we refer to as LC East, LC West, LC North, LC South and EN project areas (collectively, with the Lost Creek Project, the “Lost Creek Property”). Five of the projects at the Lost Creek Property contain reported mineral resources: Lost Creek, LC East, LC West, LC South and LC North.
Our Wyoming properties together total approximately 48,000 acres and include our Shirley Basin Project. Other non-material exploration stage projects are located in the GDB and the Lucky Mc Project is in the Gas Hills Uranium District, Wyoming. The Lost Creek Property and the Shirley Basin Project are the only two mineral properties that we deem to be individually material.
Our mineral resources reported pursuant to S-K 1300 for our material properties Lost Creek Property and Shirley Basin Project are summarized here and discussed below at “Lost Creek ISR Uranium Property S-K 1300 Mineral Resources” and “Shirley Basin ISR Uranium Project S-K 1300 Mineral Resources.”
Resource Summary (December 31, 2024)
Measured
Indicated
Inferred
Avg
Grade
Short
Tons
Pounds
Avg
Grade
Short
Tons
Pounds
Avg
Grade
Short
Tons
Pounds
Assumed
Project
% eU3O8
(X 1000)
(X 1000)
% eU3O8
(X 1000)
(X 1000)
% eU3O8
(X 1000)
(X 1000)
Pricing
Wyoming Uranium Projects
Lost Creek Property (after production)(7)
0.049
8,664
8,506
0.044
4,586
4,011
0.043
7,991
6,807
$55.00 to $87.20
Shirley Basin Project
0.269
1,412
7,598
0.116
1,290
-
-
-
$82.46 to $86.21
TOTAL
0.080
10,076
16,104
0.052
5,140
5,301
0.043
7,991
6,807
MEASURED & INDICATED
0.070
15,216
21,405
INFERRED
0.043
7,991
6,807
Notes: (please also see notes related to each of the mineral resource summary tables below, for the Lost Creek Property and the Shirley Basin Project)
1. Sum of Measured and Indicated tons and pounds may not add to the reported total due to rounding.
2. Table shows resources based on grade cutoff of 0.02 % eU3O8 and a grade x thickness cutoff of 0.20 GT.
3. Mineral processing tests have been conducted historically and by the Company and indicate that recovery should be at or about 80%, which is consistent with industry standards. Recovery at Lost Creek to date has exceeded the industry standard of 80%.
4. Measured, Indicated, and Inferred (where estimated) Mineral Resources as defined in S-K 1300.
5. Resources set forth above are reported through December 1, 2024 for Lost Creek (with production reconciled through December 31, 2024) and through December 31, 2024 for Shirley Basin.
6. All reported resources occur below the static water table at Lost Creek and below the historical, pre-mining static water table at Shirley Basin.
7. Related to Lost Creek, through December 31, 2024, 3.104 million lbs. of U3O8 have been produced from the Lost Creek Project HJ Horizon. The Lost Creek TRS reflected 2.838 million lbs. of U3O8 produced from the Lost Creek Project HJ Horizon as of December 31, 2023.
8. Mineral resources that are not mineral reserves do not have demonstrated economic viability.
9. Variable pricing for each, based upon projections of market analysts and industry experts, and assumptions for operations at each property, including sales contracts, are as shown, and set forth in the respective S-K 1300 Initial Assessments filed in March 2024.
Mineralization at our uranium properties in Wyoming typically occurs at depth and does not outcrop. Therefore, investigation of the mineralization is accomplished by drilling and related sampling and logging procedures. We maintain standards to routinely calibrate our logging tools (and require similar standards of our logging contractors), as well as utilizing established quality control procedures for sample collection, and detailed logging of drill cuttings by Company geologists to gain an understanding of redox conditions within host sandstones. The security and controls over the preparation of samples and analytical procedures data is typical among U.S. uranium industry professionals. In turn, the controls inherent in the calculation of mineral resources once the data is obtained and analyzed are recognized professional standards, and our methods have routinely been assessed and verified by third party qualified professionals through the preparation of our technical reports.
Lost Creek Property - Great Divide Basin, Wyoming
We acquired the Lost Creek Project area in 2005. Lost Creek is in the GDB, Wyoming. The permit area of the Lost Creek Project covers 4,254 acres (1,722 hectares), comprising 201 lode mining claims and one State of Wyoming mineral lease section. Regional access relies almost exclusively on existing public roads and highways. The local and regional transportation network consists of primary, secondary, local and unimproved roads. Direct access to Lost Creek is mainly on two crown-and-ditched gravel paved access roads to the processing plant. One road enters from the west from Sweetwater County Road 23N (Wamsutter-Crooks Gap Road); the other enters from the east off BLM controlled Sooner Road.
On a wider basis, from population centers, the Lost Creek property area is served by an Interstate Highway (Interstate 80), a US Highway (US 287), Wyoming state routes (SR 220 and 73 to Bairoil), local county roads, and BLM roads. The nearest airport to the Project is Casper-Natrona County International Airport located just north and west of Casper. Both Laramie and Rawlins have smaller regional airports.
The basic infrastructure (power, water, and transportation) necessary to support our ISR operation is located within reasonable proximity. Generally, the proximity of Lost Creek to paved roads is beneficial with respect to transportation of equipment, supplies, personnel and product to and from the property. Existing regional overhead electrical service is aligned in a north-to-south direction along the western boundary of the Lost Creek Project. An overhead power line, approximately two miles in length, was constructed to bring power from the existing Pacific Power line to the Lost Creek plant. Power drops have been made to the property and distributed to the plant, offices, wellfields, and other facilities. Additional power drops will be installed as we continue to expand the wellfield operations.
The Lost Creek Property is located as shown here:
Production Operations
Following receipt of the final regulatory authorization in October 2012, we commenced construction at Lost Creek. Construction included the plant facility and office building, installation of all process equipment, installation of two access roads, additional power lines and drop lines, deep disposal wells, construction of two holding ponds, a multi-purpose warehouse facility, and drill shed building. In August 2013, we received operational approval from the NRC and commenced production operations. See also discussion of the operational methods used at Lost Creek, above, under “Business and Properties.”
At year-end 2024, all wells to support the originally planned 13 header houses (“HHs”) in Mine Unit 1 (“MU1”) have been completed and have operated, as have the first 11 HHs in Mine Unit 2 (“MU2”). The first three HHs in MU2 have been producing since 2018; two new HHs came online in 2023 and six new header houses came online in 2024. We have brought HHs 2-12 and 2-13 online in Q12025.
Beginning in 2020 Q3 we maintained reduced production operations at Lost Creek. In 2021-2022, we had nominal production at Lost Creek. In December 2022, a ramp-up decision was made to return Lost Creek to commercial level production operations. In 2023, we captured 103,487 pounds U3O8 and began drying and packaging yellowcake. In 2024, we captured 265,746 pounds U3O8.
The production at Lost Creek, for the past three years, is set forth here:
Pounds U3O8 Captured
265,746
103,487
Lost Creek ISR Uranium Property S-K 1300 Mineral Resources
An updated Initial Assessment Technical Report Summary on the Lost Creek ISR Uranium Property Sweetwater County, Wyoming, USA (the “Lost Creek Report”) was filed with as an exhibit to our Annual Report of Form 10-K filed in March 2024 and provided the mineral resource estimates and preliminary economic analysis in respect of the Lost Creek Property. The Lost Creek Report was prepared by WWC Engineering. The Lost Creek Report reflects the updated mineral resource estimates, production operations, and operational and development costs to December 31, 2023.
In 2024, we continued our ramp-up of operations at Lost Creek, with additional development drilling in MU2 and MU1 Phase 2, as well delineation drilling in MU5. The drilling, generally, was not intended to expand the mineral resources, although, as was expected, the delineation drilling did identify additional inferred mineral resources. The changes to the mineral resource in other areas confirmed earlier estimates and allowed categorization of mineral resource to be heightened (e.g., from inferred to indicated and from indicated to measured). Resources recovered through production operations are subtracted from measured resources. We utilized a cut-off of December 1, 2024, with respect to estimating our mineral resources at Lost Creek to facilitate timely completion of our year-end estimate. Due to winter weather conditions and holiday slow-down, December is a considerably slower drilling month. Reconciliation of pounds recovered is reflected as at December 31, 2024.
The mineral resources at the Lost Creek Property are as follows:
Lost Creek Property - Resource Summary (December 31, 2024)
Measured
Indicated
Inferred
Avg
Grade
Short
Tons
Pounds
Avg
Grade
Short
Tons
Pounds
Avg
Grade
Short
Tons
Pounds
Project
% eU3O8
(X 1000)
(X 1000)
% eU3O8
(X 1000)
(X 1000)
% eU3O8
(X 1000)
(X 1000)
LOST CREEK
0.049
10,430
10,145
0.046
2,482
2,278
0.043
3,740
3,215
Production through 12/31/2024
0.049
(3,167)
(3,104)
-
-
-
-
-
-
LC EAST
0.052
1,401
1,465
0.042
1,883
1,568
0.042
2,954
2,481
LC NORTH
-
-
-
-
-
-
0.045
LC SOUTH
-
-
-
0.037
0.039
LC WEST
-
-
-
-
-
-
0.109
EN
-
-
-
-
-
-
-
-
-
TOTAL
0.049
8,664
8,506
0.044
4,586
4,011
0.043
7,991
6,807
MEASURED & INDICATED
0.047
13,250
12,517
INFERRED
0.043
7,991
6,807
Notes:
1. Sum of Measured and Indicated tons and pounds may not add to the reported total due to rounding.
2. % eU3O8 is a measure of gamma intensity from a decay product of uranium and is not a direct measurement of uranium. Numerous comparisons of eU3O8 and chemical assays of Lost Creek rock samples, as well as PFN logging, indicate that eU3O8 is a reasonable indicator of the chemical concentration of uranium.
3. Table shows resources based on grade cutoff of 0.02 % eU3O8 and a grade x thickness cutoff of 0.20 GT.
4. Mineral processing tests have been conducted historically and by the Company and indicate that recovery should be at or about 80%, which is consistent with industry standards. Recovery at Lost Creek to date has exceeded the industry standard of 80%.
5. Measured, Indicated, and Inferred Mineral Resources as defined in S-K 1300.
6. Mineral Resources are calculated with drilling to December 1, 2024 and recovery reconciliation figures to December 31, 2024.
7. All reported resources occur below the static water table.
8. 3.104 million lbs. U3O8 were produced from the Lost Creek Project HJ Horizon as of December 31, 2024.
9. Mineral resources that are not mineral reserves do not have demonstrated economic viability.
10. The point of reference for resources is in situ at the Property.
Information shown in the table above may differ from the disclosure requirements of the Canadian Securities Administrators. See Cautionary Note to Investors Concerning Disclosure of Mineral Resources, above.
Lost Creek Property - Resource Variance (December 31, 2024 compared to December 31, 2023)
Measured
Indicated
Inferred
Avg
Grade
Short
Tons
Pounds
Avg
Grade
Short
Tons
Pounds
Avg
Grade
Short
Tons
Pounds
Project
% eU3O8
(X 1000)
(X 1000)
% eU3O8
(X 1000)
(X 1000)
% eU3O8
(X 1000)
(X 1000)
LOST CREEK
-
-
(217)
(225)
(0.002)
Production
-
(271)
(266)
-
-
-
-
-
-
LC EAST
-
-
-
-
-
-
-
-
-
LC NORTH
-
-
-
-
-
-
-
-
-
LC SOUTH
-
-
-
-
-
-
-
-
-
LC WEST
-
-
-
-
-
-
-
-
-
EN
-
-
-
-
-
-
-
-
-
TOTAL
-
-
(217)
(225)
-
MEASURED & INDICATED
(0.001)
(90)
(165)
INFERRED
-
As discussed in the Lost Creek Report, the economic analysis upon which the mineral resources were evaluated assumes a variable price per pound U3O8 over the life of the Lost Creek Property. The pricing for anticipated sales in the report ranges from $55.00 to $87.20 per pound U3O8. The sale price in the Report for the produced uranium was based on existing and reasonably assumed sales commitments through 2030, and consensus pricing using an annual simple average of the projections of long-term pricing made by expert market analysts.
The Lost Creek Property includes six contiguous Projects: Lost Creek Project, LC East Project, LC West Project, LC North Project, LC South Project and EN Project. The fully licensed and operating Lost Creek Project is considered the core project while the others are collectively referred to as the Adjoining Projects in the Lost Creek Report. The Adjoining Projects were acquired by the Company as exploration targets to provide resources supplemental to those recognized at the Lost Creek Project. Most were initially viewed as stand-alone projects but expanded over time such that, collectively, they represent a contiguous block of land along with the Lost Creek Project.
The Main Mineral Trend of the Lost Creek uranium deposit (the “MMT”) is located within the Lost Creek Project. The East Mineral Trend (or “EMT”) is a second mineral trend of significance, in addition to the MMT, identified by historic drilling on the lands forming LC East. Although geologically similar, it appears to be a separate, but closely related, trend from the MMT.
The 2024 Lost Creek mineral resource estimate includes drill data and analyses of approximately 5,680 historic and current holes and over 3.19 million feet of drilling at the Lost Creek Project alone. With the acquisition of the Lost Creek Project, we acquired logs and analyses representing approximately 360,000 feet of data. Since our acquisition of the project, approximately 5,108 holes and wells have been drilled at Lost Creek. This figure now includes development drilling through 2024. Additionally, drilling from the Adjoining Projects, both historical and our drill programs, is included in the mineral resource estimate. This represents ~2,400 additional drill holes (1.3 million feet).
Regulatory Authorizations and Land Title of Lost Creek
Beginning in 2007, we completed all necessary applications and related processes to obtain the required permitting and licenses for the Lost Creek Project, of which the three most significant are a Source and Byproduct Materials License from the NRC (August 2011); a Plan of Operations with the BLM (Record of Decision (“ROD”))(October 2012); and a Permit and License to Mine from the WDEQ (October 2011)(“WDEQ Permit”). The WDEQ Permit includes the approval of MU1, as well as the Wildlife Management Plan, including a positive determination of the protective measures at the project for the greater sage-grouse species.
Potential risks to the accessibility of the estimated mineral resource at Lost Creek may include changes in the designation of the greater sage-grouse (sage grouse) as an endangered species by the USFWS because the Lost Creek Property lies within a sage grouse core area as defined by the State of Wyoming. (See discussion below under “Government Regulations, Protection of Endangered and Protected Species.”) The Company continues to work closely with the Wyoming Game and Fish Department (“WGFD”) and the BLM to mitigate impacts to the sage grouse.
The timing restrictions developed by the State preclude exploration drilling and other non-operational based activities which may disturb the sage grouse. The sage grouse timing restrictions relevant to ISR production and operational activities at Lost Creek are somewhat different because the State has recognized that mining projects within core areas must be allowed to operate year-round. While our sage grouse adaptive management plan includes certain calendar restrictions on drilling and construction activities, there are no calendar restrictions on production and operational activities in pre-approved disturbed areas within our permit to mine, and the limitations in the sage grouse management plan are not expected to affect our planned production profile.
Additional authorizations from federal, state and local agencies for the Lost Creek project include: WDEQ-Air Quality Division Air Quality Permit and WDEQ-Water Quality Division Class I Underground Injection Control (“UIC”) Permit. Following the plugging of one of our deep disposal wells in 2019, the UIC permit allows Lost Creek to operate up to four Class I injection wells to meet the anticipated disposal requirements for the life of the Lost Creek Project. The Environmental Protection Agency (“EPA”) issued an aquifer exemption for the Lost Creek project. The WDEQ’s separate approval of the aquifer reclassification is a part of the WDEQ Permit. We also received approval from the EPA and the Wyoming State Engineer’s Office for the construction and operation of two holding ponds at Lost Creek. Application has been made to the BLM for a right-of-way for use of portions of an existing regional road.
In 2014, applications for amendments to the Lost Creek license were submitted to federal regulatory agencies, NRC and BLM, for the development and mining of the LC East Project. The BLM issued its ROD authorizing the plan in 2019. The NRC participated in this review as a cooperating agency. In 2018, Wyoming assumed responsibility from the NRC for the regulation of radiation safety at uranium recovery facilities like Lost Creek. The Wyoming State Uranium Recovery Program (“URP”), a part of the WDEQ, oversees the licensing process for source material licenses as well as the operations of licensees in Wyoming. The URP has demonstrated that its integration into the overall WDEQ oversight of uranium recovery streamlines the process of licensing, offers greater consistency in authorizations and oversight, and results in reduced costs in the licensing phase. The URP issued a source material license for LC East in 2021. Also in 2021, we submitted a license renewal for the Lost Creek source material license. The renewal is under technical review with the URP.
A permit amendment requesting approval to mine at the LC East Project was also submitted to the WDEQ. The air quality permit for Lost Creek will be revised to account for additional surface disturbance at the LC East Project. Certain of our earlier Sweetwater County approvals have been amended. Numerous well permits from the State Engineer’s Office will be required. It is anticipated that the remaining permit to mine amendment and aquifer exemption will be completed prior to our planned production schedule.
During 2016, we received all authorizations for the operation of Underground Injection Control (UIC) Class V wells at Lost Creek, and operation of the circuit began in early 2017. This allows for the onsite reinjection of fresh permeate (i.e., clean water) into relatively shallow Class V wells. Site operators use the RO circuits, which were installed during initial construction of the plant, to treat process wastewater into brine and permeate streams. The brine stream continues to be disposed of in the UIC Class I deep wells while the clean permeate stream is injected into the UIC Class V wells after treatment for radium. These operational procedures have significantly enhanced wastewater capacity at the site, ultimately reducing the injection requirements of our Class I deep disposal wells and extending the life of those valuable assets.
Through our subsidiaries Lost Creek ISR, LLC and NFU Wyoming, we control the federal unpatented lode mining claims and State of Wyoming mineral leases which make up the Lost Creek Property. Title to the mining claims is subject to rights of pedis possessio against all third-party claimants so long as the claims are maintained. The mining claims do not have an expiration date. Affidavits have been timely filed with the BLM and recorded with the Sweetwater County Recorder attesting to the payment for the Lost Creek Property mining claims of annual maintenance fees to the BLM as established by law from time to time.
The state leases have a ten-year term, subject to renewal for successive ten-year terms. The surface of all the unpatented mining claims is controlled by the BLM, and we have the right to use as much of the surface as is necessary for exploration and mining of the claims, subject to compliance with all federal, state and local laws and regulations. Surface use on BLM lands is administered under federal regulations. Similarly, access to state-controlled land is largely inherent within a State of Wyoming mineral lease, with certain additional obligations to those holding surface rights on a lease-specific basis.
There are no royalties at the Lost Creek Project, except on the State of Wyoming mineral lease as provided by law. Currently, there is only limited production planned from the state leased lands. There is a production royalty of one percent on certain claims of the LC East Project, and other royalties on certain claims at the LC South and EN Projects, as well as the other State of Wyoming mineral leases (LC West and EN projects).
Together with the Lost Creek Project, Five Adjoining Projects Form the Lost Creek Property
The LC East Project (5,750 acres) was added to the Lost Creek Property in 2011-2012. We located additional unpatented lode mining claims in 2014. Our LC East Project, as discussed elsewhere in this annual report, now has a source material license and awaits only the WDEQ permit to mine before all major authorizations are in hand to recover uranium at the project. The Lost Creek Report recommends that we continue to progress all remaining permit amendments to allow for future uranium recovery.
The LC West Project (3,840 acres) was also added to the Lost Creek Property in 2011-2012. The land position here includes one State of Wyoming mineral lease, in addition to the unpatented lode mining claims. We possess data related to historical exploration programs of earlier operators.
The LC North Project (6,260 acres) is located to the north and to the west of the Lost Creek Project. Historical wide-spaced exploration drilling on this project consisted of 175 drill holes. We have conducted two drilling programs at the project. We may conduct exploration drilling at LC North to pursue the potential of an extension of the MMT of the Lost Creek Project.
The map below shows the Lost Creek Property, including the Adjoining Projects.
The LC South Project (10,200 acres) is located to the south and southeast of the Lost Creek Project. Historical drilling on the LC South Project consisted of 488 drill holes. In 2010, we drilled 159 exploration holes (total, 101,270 feet) which confirmed numerous individual roll front systems occurring within several stratigraphic horizons correlative to mineralized horizons in the Lost Creek Project. Also, a series of wide-spaced drill holes were part of this exploration program which identified deep oxidation (alteration) that represents the potential for several additional roll front horizons.
The EN Project (5,160 acres) is adjacent to and east of LC South, including unpatented lode mining claims and one State of Wyoming mineral lease. We have over 50 historical drill logs from the EN project. Some minimal, deep, exploration drilling has been conducted at the project. No mineral resource is yet reported due to the limited nature of the data.
History and Geology of the Lost Creek Property
Uranium was discovered in the Great Divide Basin, where Lost Creek is located, in 1936. Exploration activity increased in Wyoming in the early 1950s after the Gas Hills District discoveries, and continued to increase in the 1960s, with the discovery of numerous additional occurrences of uranium. Wolf Land and Exploration (which later became Inexco), Climax (Amax) and Conoco Minerals were the earliest operators in the Lost Creek area and made the initial discoveries of low-grade uranium mineralization in 1968. Kerr-McGee, Humble Oil, and Valley Development, Inc. were also active in the area. Drilling within the current Lost Creek Project area from 1966 to 1976 consisted of approximately 115 wide-spaced exploration holes by several companies including Conoco, Climax, and Inexco.
Texasgulf acquired the western half of what is now the Lost Creek Project in 1976 through a joint venture with Climax and identified what is now referred to as the MMT. In 1978, Texasgulf optioned into a 50% interest in the adjoining Conoco ground to the east and continued drilling, fully identifying the MMT eastward to the current project boundary; Texasgulf drilled approximately 412 exploration holes within what is now the Lost Creek Project. During this period Minerals Exploration Company (a subsidiary of Union Oil Company of California) drilled approximately eight exploration holes in what is currently the western portion of the Lost Creek Project. Texasgulf dropped the project in 1983 due to declining market conditions. The ground was subsequently picked up by Cherokee Exploration, Inc. which conducted no field activities.
In 1987, Power Nuclear Corporation (also known as PNC Exploration) acquired 100% interest in the project from Cherokee Exploration, Inc. PNC Exploration conducted a limited exploration program and geologic investigation, as well as an evaluation of previous in situ leach testing by Texasgulf. PNC Exploration drilled a total of 36 holes within the current project area.
In 2000, New Frontiers Uranium, LLC acquired the property and database from PNC Exploration, but conducted no drilling or geologic studies. New Frontiers Uranium, LLC later transferred the Lost Creek Project-area property along with its other Wyoming properties to its successor NFU Wyoming. In 2005, Ur-Energy USA purchased 100% ownership of NFU Wyoming.
The Lost Creek Property is situated in the northeastern part of the GDB which is underlain by up to 25,000 ft. of Paleozoic to Quaternary sediments. The GDB lies within a unique divergence of the Continental Divide and is bounded by structural uplifts or fault displaced Precambrian rocks, resulting in internal drainage and an independent hydrogeologic system. The surficial geology in the GDB is dominated by the Battle Spring Formation of Eocene age. The dominant lithology in the Battle Spring Formation is coarse arkosic sandstone, interbedded with intermittent mudstone, claystone and siltstone. Deposition occurred as alluvial-fluvial fan deposits within a south-southwest flowing paleodrainage. The sedimentary source is considered to be the Granite Mountains, approximately 30 miles to the north. Maximum thickness of the Battle Spring Formation sediments within the GDB is 6,000 ft.
Uranium mineralization identified throughout the property occurs as roll front type deposits, typical in most respects of those observed in other Tertiary Basins in Wyoming. Uranium deposits in the GDB are found principally in the Battle Spring Formation, which hosts the Lost Creek Property deposit. Lithology within the Lost Creek deposit consists of approximately 60% to 80% poorly consolidated, medium to coarse arkosic sands up to 50 ft. thick, and 20% to 40% interbedded mudstone, siltstone, claystone and fine sandstone, each generally less than 25 ft. thick. This lithological assemblage remains consistent throughout the entire vertical section of interest in the Battle Spring Formation.
Outcrop at Lost Creek is exclusively that of the Battle Spring Formation. Due to the soft nature of the formation, the Battle Spring Formation occurs largely as sub-crop beneath the soil. The alluvial fan origin of the formation yields a complex stratigraphic regime which has been subdivided throughout Lost Creek into several thick horizons dominated by sands, with intervening named mudstones. Lost Creek is currently licensed and permitted to produce from the HJ horizon. The LC East license amendments include authorizations to recover uranium from the HJ and KM horizons, while the amendment to the Lost Creek Project will allow expansion of recovery into additional HJ horizon resource areas.
Shirley Basin Mine Site (Shirley Basin, Wyoming)
As a result of the Pathfinder acquisition, we own the Shirley Basin Project, from which Pathfinder and its predecessors historically produced more than 28 million pounds of U3O8, primarily from the 1960s until the early 1990s. Pathfinder’s predecessors included COGEMA, Lucky Mc Uranium Corporation, and Utah Construction/Utah International. Shirley Basin conventional mine operations were suspended in the 1990s due to low uranium pricing, and facility reclamation was substantially completed. After the cessation of open pit uranium mining operations at Shirley Basin in 1992, two historical resource areas on the project were identified as potentially suitable for ISR mining. These two areas are the FAB Resource Area or FAB Trend and Area 5.
We control approximately 3,536 acres of property interests in the general area of the project which is located in central southeast Wyoming, approximately 40 miles south of Casper. The project is accessed by travelling west from Casper, on Highway 220. After travelling 18 miles, turn south on Highway 487 and travel an additional 35 miles; the entrance to the Shirley Basin Project is to the east. The project is in an unpopulated area located in the northeastern portion of Carbon County, Wyoming. It is centered at approximately 42 degrees, 22 minutes north latitude and 106 degrees, 11 minutes west longitude, in T28N, R78W, within the 6th principal meridian.
The nearest airport to the project is Casper-Natrona County International Airport located just north and west of Casper, Wyoming. Both Laramie and Rawlins have smaller regional airports. The BNSF Railroad runs through Casper, and the Union Pacific railroad runs through Medicine Bow.
Site infrastructure is excellent. A road which traverses the project and provides access from the south was upgraded and other roads were constructed in 2024. A septic system has been installed. Several support facilities remain from the historical operations, which are being refurbished to house drilling and casing supplies, maintenance and offices. A regional power transmission line (69 kV) passes through the northern portions of the project. An existing energized power line leads to a substation near the field office, and from there additional power lines have been installed to the FAB Trend. The historical substation is currently being refurbished with the goal of completing the upgrade early in Q4 2025. A backup trailer-mounted substation is available if the upgrade is not timely completed.
A licensed waste disposal site for 11e.(2) byproduct material is currently operating adjacent to the fully reclaimed tailings complex. The tailings facility at the Shirley Basin site is one of the few remaining facilities in the U.S. that is licensed to receive and dispose of by-product waste material from other in situ uranium mines. We assumed operation of the byproduct disposal site in 2013 and continue to accept deliveries under several existing contracts.
Water supply needs have been limited to drilling water and incidental use. Drilling needs have been supplied by one water well capable of producing over 25 gallons per minute (gpm). Several backup water wells are also present. Although none of the backup wells has been utilized to date, we have recently permitted one well (capable of production at approximately 50 gpm) to repurpose it temporarily for additional supply needs. The existing water wells can provide sufficient supply for domestic and other potential operational requirements. Additional new and appropriately sited water source wells may be considered for future needs. Water impounded in the reclaimed mine pits is suitable for use in drilling and other non-potable uses would be available pending construction of approach ramps.
Within the project, the now permitted area (2,605 acres) consists of 1,770 acres of locatable mineral lands that we control, and which will allow us to recover uranium from both the FAB and Area 5 Resource Areas. This total consists of 1,330 acres of U.S. lode mining patents (nine patents), 370 acres of federal unpatented lode mining claims (29 claims), and 70 acres (two tracts) of fee minerals. Together with these mineral rights, we control 280 acres of additional surface access rights necessary to develop the project.
As with the Lost Creek mining claims, title to the unpatented mining claims at Shirley Basin is subject to rights of pedis possessio against all third-party claimants as long as the claims are maintained. The mining claims do not have an expiration date. Affidavits have been timely filed with the BLM and recorded with the Carbon County Clerk attesting to the payment for the mining claims of annual maintenance fees to the BLM as established by law from time to time. The surface of all the unpatented mining claims is controlled by the BLM, and we have the right to use as much of the surface as is necessary for exploration and mining of the claims, subject to compliance with all federal, state and local laws and regulations. Surface use on BLM lands is administered under federal regulations.
There are no production royalties at the FAB Resource Area. Within Area 5, approximately 202 acres are subject to a formulaic royalty interest which totals approximately 0.5%. On two other tracts at Area 5 (30 acres in the southern portion and 40 acres in the southeastern portion), uranium and associated minerals are subject to different formulaic royalties which are approximately 1%. Currently, there is no known mineral resource on these 70 acres. A 0.5% royalty was included for the resources in Area 5. Additionally, certain use fees are in place on some lands in Area 5, based upon an annual disturbance-level calculation.
All major authorizations, permits and licenses for the project have been received. Additional minor permits/authorizations will be required before operations begin; each of the remaining authorizations is routine and may commonly be obtained in days or weeks.
Shirley Basin ISR Uranium Project S-K 1300 Mineral Resources
An updated Initial Assessment Technical Report Summary on the Shirley Basin ISR Uranium Project Carbon County, Wyoming USA, as amended (the “Shirley Basin Report”) was filed with our Annual Report on Form 10-K/A filed in March 2024 and provides the mineral resource estimates and preliminary economic analysis in respect of the Shirley Basin Project. The Shirley Basin Report was prepared by WWC Engineering. The Shirley Basin Report reflects updated detailed planning of wellfields, construction plans and operational and development costs to December 31, 2023.
While we conducted only a nominal amount of drilling at Shirley Basin during 2024, which was primarily installation of monitor wells and other design-oriented drillholes, the mineral resource estimate for the project changed slightly. Mineral resources at the Shirley Basin Project at December 31, 2024 are as follows:
Shirley Basin Project - Resource Summary (December 31, 2024)
Measured
Indicated
Avg Grade
Short Tons
Pounds
Avg Grade
Short Tons
Pounds
Resource Area
% eU3O8
(X 1000)
(X 1000)
% eU3O8
(X 1000)
(X 1000)
FAB TREND
0.273
1,218
6,653
0.117
1,081
AREA 5
0.243
0.115
TOTAL
0.269
1,412
7,598
0.116
1,290
MEASURED & INDICATED
0.226
1,966
8,888
Notes:
1. Sum of Measured and Indicated tons and pounds may not add to the reported total due to rounding.
2. Based on grade cutoff of 0.020 % eU3O8 and a grade x thickness (GT) cutoff of 0.25 GT.
3. Mineral processing tests have been conducted historically and by the Company and indicate that recovery should be at or about 80%, which is consistent with industry standards.
4. Measured and Indicated mineral resources as defined in S-K 1300.
5. All reported resources occur below the historical, pre-mining static water table.
6. Average grades are calculated as weighted averages. The minor change to the average grade at the FAB Trend is the result of 2024 drilling and the minor addition to the resource.
7. Mineral resources that are not mineral reserves do not have demonstrated economic viability.
8. The economic analysis upon which the mineral resources were evaluated assumes a variable price per pound for U3O8 over the life of the Shirley Basin Project, as discussed in the Shirley Basin Report. The projected pricing for anticipated sales ranges from $82.46 to $86.21 per pound U3O8.
9. The point of reference for resources is in situ at the project.
Information shown in the table above may differ from the disclosure requirements of the Canadian Securities Administrators. See Cautionary Note to Investors Concerning Disclosure of Mineral Resources, above.
The Shirley Basin mineral resource estimate includes drill data and analyses of approximately 3,200 holes and nearly 1.2 million feet of historic drilling at the Shirley Basin Project. In 2014, we drilled 14 confirmation holes representing approximately 6,600 feet which were included in the mineral resource estimate. Because of the density of the historical drill programs, estimates are made entirely in
Measured and Indicated categories of resources. There is no Inferred resource category included in the estimate for Shirley Basin. Studies we conducted in 2014, and studies by Pathfinder in the late 1990s, indicate that this mineralization is amenable to ISR extraction.
There has been no material change in the mineral resources estimated in the Shirley Basin Report (mineral resources at December 31, 2023). The drilling we conducted in 2024 was primarily for the installation of monitor wells and was not designed to delineate additional resources. In addition to the 125 monitor wells, we drilled approximately 25 holes to obtain additional information for planning and design of the wellfield. In the process of drilling wells interior to the FAB Trend, and continuing our analyses of Area 5, there is a resulting additional mineral resource of a non-material amount (~72,000 pounds). The information obtained through the drill program will inform our planning for development and operational activities.
Shirley Basin Project - Resource Variance (December 31, 2024 compared to December 31, 2023)
Measured
Indicated
Avg Grade
Short Tons
Pounds
Avg Grade
Short Tons
Pounds
Resource Area
% eU3O8
(X 1000)
(X 1000)
% eU3O8
(X 1000)
(X 1000)
FAB TREND
(0.007)
(0.002)
-
AREA 5
-
(1)
(2)
-
(2)
(5)
TOTAL
(0.006)
(0.002)
(5)
MEASURED & INDICATED
(0.004)
Additional Shirley Basin History and Geology
The Shirley Basin Project lies in the northern half of the historic Shirley Basin uranium mining district (the “District”), which is the second most prolific uranium mining district in Wyoming. Earliest discoveries were made in 1954 by Teton Exploration. This was followed by an extensive claim staking and drilling rush by several companies in 1957. Several important discoveries were made, and the first mining was started in 1959 by Utah Construction Corp. (predecessor to Pathfinder). Underground mining methods were initially employed but encountered severe groundwater inflow problems, so in 1963 Utah Construction switched to solution mining methods. This was the first commercially successful application of in situ solution mining recovery (ISR) for uranium in the U.S. In 1968 market and production needs caused Utah Construction to move to open-pit mining and a conventional mill. All production within the District after 1968 was by open-pit methods.
As described, several companies operated uranium mines within the District, however three companies were dominant. Utah Construction/Pathfinder’s efforts were focused on the northern portion of the District, while Getty was largely in the central portion, and Kerr-McGee was in the southern portion. The last mining in the District concluded in 1992 when Pathfinder shut down production due to market conditions. Total production from the Shirley Basin District was 51.3 million pounds of U3O8, of which 28.3 million pounds U3O8 came from the Utah Construction/Pathfinder operations. The uranium resources which we are planning to produce through ISR represent unmined extensions of mineral trends addressed in past open-pit mines. These extensions were targeted for recovery years ago but were not developed prior to the end of operations in 1992.
The District lies in the north-central portions of the Shirley Basin geologic province, which is one of several inter-montane basins in Wyoming created 35-70 million years ago (mya) during the Laramide mountain building event. The Basin is floored by folded sedimentary formations of Cretaceous age (35-145 mya). In the northern half of the District the Cretaceous units were later covered by stream sediments of the Wind River Formation of Eocene age (34-56 mya) which filled paleo-drainages cut into a paleo-topographic surface. The Wind River Formation was subsequently covered by younger volcanic ash-choked stream sediments of the White River and Arikaree Formations of Oligocene age (23-34 mya) and Miocene age (5-23 mya), respectively. Uranium occurs as roll front type deposits along the edge of large regional alteration systems within sandstone units of the Wind River Formation. The source of the uranium is considered to be the volcanic ash content within the overlying White River Formation and also granitic content within the Wind River Formation itself.
In the project area, the primary hosts for uranium mineralization are arkosic sandstones of the Eocene-age Wind River Formation. The White River Formation unconformably overlies the Wind River Formation and outcrops on the surface throughout most of the project, with thicknesses ranging from a thin veneer in the FAB Resource Area to over 250 ft. in Area 5. The Wind River sediments in the project area were deposited as part of a large fluvial depositional system. The lithology of the Wind River Formation is characterized by thick, medium to coarse-grained, arkosic sandstones separated by thick claystone units. Sandstones and claystones are typically 20 - 75 ft. thick. Minor thin lignite and very carbonaceous shale beds occur locally. These fluvial sediments are located within a large northwest-trending paleochannel system with a gentle 1° dip to the north (Bailey and Gregory, 2011). The average thickness of the Wind River Formation within the project is approximately 230 ft. The Main and Lower Sands of the Wind River Formation are the primary hosts to mineralization which we are currently targeting for ISR development.
The Lower Sand represents the basal sand unit of the Wind River Formation and in places lies directly above the underlying Cretaceous formations. The Main Sand typically lies approximately 15 - 25 ft. above the Lower Sand. Locally, the two sands merge where the intervening claystone unit is absent. Typical thickness of the Lower Sand ranges from 25 - 50 ft. and that of the Main Sand from 40 - 75 ft. Less dominant sands are common within the Wind River Formation. One in particular has been referred to as the Upper Sand and is present within much of the FAB Trend, lying approximately 25 ft. above the Main Sand. Claystone units are normally at least 10 ft. thick and commonly are 20 - 50 ft. thick.
Summary Information Concerning Additional Non-Material Exploration Stage Projects
In addition to the Lost Creek Property and Shirley Basin Project, the Company controls mineral properties for six additional projects in the GDB (four) and the Gas Hills Uranium District (one) in Wyoming and in Mineral County, Nevada (one, proximate to the Camp Douglas and Candelaria Mining Districts).
Each of the following described uranium exploration stage projects is 100% owned and controlled by our exploration and land holding company, NFU Wyoming, except the Lucky Mc project which is held by Pathfinder. Mineral resource estimations for the following projects pursuant to S-K 1300 have not been completed. Each of the uranium projects contains roll-front style uranium mineralization and appear to be amenable to ISR, pending further exploration and analysis at each. We have historical data on each of the properties, as well as drill data and/or other exploration data from our exploration work at several of the projects. Future exploration activities for the Wyoming uranium projects are anticipated to be further drilling, which would proceed pursuant to drilling notices obtained from the WDEQ and BLM. There is no ongoing production at any of these mineral projects. Because of the persistent downturn in the uranium market in recent years, we maintained our focus on operations at Lost Creek and the permitting process and development of Shirley Basin, while deferring costs of exploration at other projects. As we continue to ramp-up our production operations at Lost Creek, and build out Shirley Basin for operations, our financial priorities will primarily remain with those projects.
The map below provides the location of each of the additional projects in the GDB, Wyoming, including their proximity to the Lost Creek Property.
Arrow Project is an exploration stage uranium project (10 unpatented lode mining claims; approximately 190 acres) located in Sections 30-31, T26N, R94W (Sweetwater County, Wyoming).
Lost Soldier is an exploration stage uranium project located in Sweetwater County, Wyoming on 105 unpatented lode mining claims. Located in Sections 5-8 and 17-18, T26N, R90W and Sections 1 and 11-14, T26N, R91W, the project covers approximately 1,960 acres.
North Hadsell Project is an exploration stage uranium project, comprising 203 unpatented lode mining claims located in Sections 3-5 and 8-10, T26N, Range 91W (Sweetwater County) and Sections 31-34, T 27N, R91W and Sections 21-23, 25-28, 33-34 and 36 T27N, R92W (Fremont County) in Wyoming. The project controls approximately 3,970 acres.
RS Project is an exploration stage uranium project of 54 unpatented lode mining claims totaling an area of approximately 920 acres, located in Sections 6 and 7, T27N, R92W and Sections 1 and 2, T27N, R93W.
Our Lucky Mc Project is in the Gas Hills Uranium District, Fremont County, Wyoming. An historic mine site, Pathfinder holds 100% mineral interests at the project through three mineral patents (totaling approximately 970 acres) located in Sections 2 and 3, T32N, R90W, and Sections 21, 22-27 and 35, T33N, R90W; two State of Wyoming mineral leases (together, approximately 410 acres) located in Section 36, T33N, R90W, Section 1, T32N, R91W; and Sections 6 and 7, T32N, R90W; and two unpatented lode mining claims (together, approximately 40 acres) located in Section 6, T32N, R90W and Section 1, T32N, R91W. In 2021, the historic permit to mine was terminated and related reclamation bond and obligations released. Further exploration or development would be accomplished through drill notices and routine permitting and licensing through the WDEQ and/or BLM.
Our exploration stage gold project, the Excel Project, is in west-central Nevada, and comprises 93 unpatented lode mining claims (~1,900 acres) in Sections 9, 10, 20-22, 26-29, T5N, R34E. The Excel Project is 100% held by NFU Wyoming. The project is located within the Excelsior Mountains, in Mineral County, Nevada. We have historical geologic data, as well as data obtained through early-stage field programs including rock sampling, geochemical soil sampling and drill programs, together with geophysical studies. Further drilling would require additional notice-level permits or plan of operations obtained from the BLM.
Competition and Mineral Prices
The uranium industry is highly competitive, and our competition includes larger, more established companies with longer operating histories that not only explore for and produce uranium, but also market uranium and other products on a regional, national or worldwide basis. On a global basis, this competition continues to include a significant number of state-owned or sponsored entities. Because of the greater financial resources of these companies, competitive bid processes on off-take sales agreements remain difficult. Beyond that, in the U.S., the competitive bid process for other contracts and opportunities is and will be challenging; this competition extends to the further acquisition and development of properties. Additionally, these larger (or state-owned) companies have greater resources to continue with their operations during periods of depressed and volatile market conditions.
Unlike other commodities, uranium does not trade on an open market. Contracts are negotiated privately by buyers and sellers. Since 2022, we have secured new term agreements for sales of uranium at fixed pricing and other set delivery terms. Under our agreements, base quantity deliveries between 440,000 and 1,300,000 pounds U3O8 annually are expected to be delivered from 2025 through 2030; additional commitments of 100,000 pounds U3O8 per year have been made to a customer in 2032 and 2033. Several of our sales agreements permit the customer to ‘flex’ the base annual delivery quantity up or down by up to 10% of the base amount and in some cases extend the deliveries into subsequent years.
Uranium prices are published by two of the leading industry-recognized independent market consultants, UxC, LLC and TradeTech, LLC, who publish on their respective websites. The following information reflects an average of the per pound prices published by these two consulting groups for the end of the periods indicated:
End of Year:
Spot price (US$)
$
24.93
$
30.20
$
42.05
$
47.68
$
91.00
$
72.63
LT price (US$)
$
32.50
$
35.00
$
42.75
$
52.00
$
68.00
$
80.50
End of Month:
11/30/24
12/31/24
01/31/25
02/28/25
03/31/25
04/09/25
Spot price (US$)
$
77.13
$
72.63
$
69.28
$
65.03
$
64.23
$
64.80
LT price (US$)
$
81.50
$
80.50
$
81.00
$
80.00
$
80.00
$
80.00
The long-term price as defined by UxC, LLC includes conditions for escalation (from current quarter) delivery timeframe (≥ 36 months), and quantity flexibility (up to ±10%) considerations.
Strong competition in the uranium industry is also felt in the pursuit of qualified personnel and contractors, drill companies and equipment, and other equipment and materials. As the industry is revitalized through changes in market pricing and other fundamental changes in the uranium market, this type of competition for expertise, staffing and equipment has become more significant and is expected to remain challenging. Additionally, in Wyoming, inter-industry competition for qualified labor is more challenging during times in which oilfield and renewable energy projects maintain or increase staffing levels.
Government Regulations
As set forth above, our operations at Lost Creek and our other projects in Wyoming and other locations where exploration, development and operations are taking place, are subject to extensive laws and regulations which are overseen and enforced by multiple federal, state and local authorities. These laws and regulations govern exploration, development, production, various taxes, labor standards, occupational health and safety including radiation safety, waste disposal, underground source of drinking water, protection and remediation of the environment, protection of endangered and protected species, toxic and hazardous substances and other matters. Uranium minerals exploration is also subject to risks and liabilities associated with pollution of the environment and disposal of waste products occurring as a result of mineral exploration and production.
Compliance with these laws and regulations imposes substantial costs on us and may subject us to significant potential liabilities or impacts to operations or project development. Changes in these regulations could require us to expend significant resources to comply with new laws or regulations or changes to current requirements and could have a material adverse effect on our business operations. Compliance with all current regulations, including but not limited to the environmental and safety regulatory schemes, is an integral part of our day-to-day business, management and staff commitment and expenditures. The costs attendant to compliance are understood and routinely budgeted and are generally comparable to those of other U.S. uranium companies and other natural resources companies in the U.S. and Canada. It should be noted that environmental protections and regulatory oversight thereof vary significantly outside North America, particularly in Kazakhstan and Russia, where state-owned enterprises operate with only limited or more relaxed regulatory oversight related to environmental and worker safety.
Mineral exploration and development activities, as well as our uranium recovery operations, are subject to comprehensive regulation which may cause substantial delays, restrictions or require capital outlays in excess of those anticipated, causing an adverse effect on our business operations. Mineral exploration operations are also subject to federal and state laws and regulations which seek to maintain health and safety standards. Various permits from government bodies are required for drilling operations to be conducted; no assurance can be given that such permits will be received. Environmental standards imposed by federal and state authorities may be changed and any such changes may have material adverse effects on our activities. Mineral recovery operations are subject to federal and state laws relating to the protection of the environment, including laws regulating removal of natural resources from the ground and the discharge of materials into the environment. The posting of a performance bond and the costs associated with our permitting and licensing activities requires a substantial budget and ongoing cash commitments. In addition to pursuing ongoing permitting and licensure for new projects and additions to our existing Lost Creek Project, these expenditures include ongoing monitoring (e.g., wildlife, groundwater and effluent monitoring) and other activities to ensure regulatory and legal compliance, as well as compliance with our permits and licenses. Costs for these activities may increase and we may be required to increase compliance activities in the future, which might further affect our ability to expand or maintain our operations.
Our mineral projects are subject to the General Mining Law, as amended, and myriad related regulatory programs. Over several decades, numerous attempts have been made to amend the General Mining Law which authorizes and governs mining on federal lands. Various recent proposals have included the addition of royalty payments, changes to tribal consultation, addition of a reclamation fee, addition of a tax on displaced material and other actions which may have a material impact on in situ mining operations on federal lands. Each attempt to significantly amend the General Mining Law has failed. We anticipate attempts to amend the law will recur.
The Lost Creek Project, which is primarily on federal lands, operates under a Plan of Operations approved by the BLM as prescribed by law. The Shirley Basin Project also has an approved Plan of Operations because a portion of the project is on federal lands. Previous draft amendments to the General Mining Law included provisions ‘grandfathering’ existing permitted operations from certain new restrictions, taxes, or fees, but it is unknown if future proposals will contain similar exceptions.
Environmental Regulations
As set forth above, our mineral projects are the subject of extensive environmental regulation at federal and state levels. Exploration, development and production activities are subject to certain environmental regulations which may prevent or delay the commencement or continuance of our operations. The National Environmental Protection Act (“NEPA”) affects our operations as it requires federal agencies to consider the significant environmental consequences of their proposed programs and actions and inform the public about their decision making. The required process of NEPA may take many months or even years to complete. Currently, we are not pursuing federal permits or licenses which are subject to NEPA.
In general, our exploration and production activities are subject to certain federal and state laws and regulations relating to environmental quality and pollution control. Such laws and regulations increase the costs of these activities substantially and may prevent or delay the commencement or continuance of a given operation. Because compliance with current laws and regulations is an integral part of our industry and business it has not had a materially adverse effect on our operations or financial condition to date in relation to our U.S. peers. Specifically, we are subject to legislation and regulations regarding radiation safety, emissions into the environment, water discharges, and storage and disposition of hazardous wastes. In addition, the law requires well and facility sites to be abandoned and reclaimed to the satisfaction of state and federal authorities.
Protection of Endangered and Protected Species
Our sites are subject to federal laws and regulations with respect to the protection of endangered and protected species, including the Endangered Species Act (ESA). Notably, potential changes in the designation of the greater sage-grouse (sage grouse) as an endangered species by the USFWS are monitored closely because the Lost Creek Property lies within a sage grouse core area as defined by the State of Wyoming. In 2015, the USFWS issued its finding that the greater sage grouse does not warrant protection under the ESA. The USFWS reached this determination after evaluating the species’ population status, along with the collective efforts by the BLM and U.S. Forest Service, state agencies, private landowners and other partners to conserve its habitat.
After a thorough analysis of the best available scientific information and considering ongoing key conservation efforts and their projected benefits, the USFWS determined the species does not face the risk of extinction in the foreseeable future and therefore does not need protection under the ESA. Should future decisions vary, or state or federal agencies alter their management of the species, there could potentially be an impact on future expansion operations. However, the Company continues to work closely with the Wyoming Game and Fish Department (“WGFD”) and the BLM to mitigate impacts to the sage grouse. Long-term monitoring of sage grouse populations has shown that the “affected” populations at Lost Creek are on a parallel trend with “reference” populations located beyond the potential influence of the project. Trends vary considerably based on a variety of environmental factors including, most importantly, annual moisture.
The State of Wyoming has developed a “core-area strategy” to help protect the sage grouse within certain core areas of the state. The Lost Creek Property is within a designated core area and is thus subject to work activity calendar restrictions pursuant to the core-area strategy. The timing restriction precludes exploration drilling and other non-operational based activities which may disturb the sage grouse. The sage grouse timing restrictions relevant to ISR production and operational activities at Lost Creek are somewhat different because the State has recognized that mining projects within core areas must be allowed to operate year-round. While our approved sage grouse adaptive management plan includes certain calendar restrictions on drilling and construction activities, there are no calendar restrictions on production and operational activities in pre-approved disturbed areas within our permit to mine, and the limitations in the sage grouse management plan are not expected to affect our planned production profile.
The BLM also prepared and issued environmental impact statements for, and issued amendments to, Resource Management Plans related to the sage grouse, which have been amended from time to time.
Other assessments of wildlife and plant life are periodically made by federal regulators.
State of Wyoming
As discussed elsewhere in this annual report, we are regulated by multiple divisions of the State of Wyoming Department of Environmental Quality (LQD, WQD, AQD and URP), the State Engineer’s Office and other state agencies. As a state program with delegated authority of the NRC, the URP will adopt future regulations and rulemakings of the NRC on a time-to-time basis. In 2019 NRC staff made recommendations to the NRC Commissioners that regulations for in situ recovery operations should be developed. NRC staff, in close consultation with agreement state programs, worked to draft a rulemaking. No recent advances have been made. It is unknown whether or when the NRC may return to the rulemaking.
Waste Disposal
The Resource Conservation and Recovery Act (“RCRA”), and comparable state statutes, affect minerals exploration and production activities by imposing regulations on the generation, transportation, treatment, storage, disposal and cleanup of hazardous wastes and on the disposal of non-hazardous wastes. Under the auspices of the U.S. Environmental Protection Agency (the “EPA”), the individual states administer some or all the provisions of RCRA, sometimes in conjunction with their own, more stringent requirements.
Underground Injection Control (“UIC”) Permits
The federal Safe Drinking Water Act (“SDWA”) creates a nationwide regulatory program protecting groundwater. This act is administered by the EPA. However, to avoid the burden of dual federal and state regulation, the SDWA allows for the UIC permits issued by states to satisfy the UIC permit required under the SDWA under two conditions. First, the state’s program must have been granted primacy, as is the case in Wyoming. Second, the EPA has continuing authority to review and determine whether requested aquifer exemptions are approved. The EPA may delay or decline to process the state’s application if the EPA questions the state’s jurisdiction over the mine site. From time to time, EPA has promulgated rulemaking processes to expand and/or clarify its jurisdiction and the rules under which the UIC and other programs operate; while no such rulemaking is currently in process, there may be additional such rulemakings at any time.
CERCLA
The federal Comprehensive Environmental Response, Compensation and Liability Act (“CERCLA”) imposes joint and several liability for costs of investigation and remediation and for natural resource damages, without regard to fault or the legality of the original conduct, on certain classes of persons with respect to the release into the environment of substances designated under CERCLA as hazardous substances (“Hazardous Substances”). These classes of persons or potentially responsible parties include the current and certain past owners and operators of a facility or property where there is or has been a release or threat of release of a Hazardous Substance and persons who disposed of or arranged for the disposal of the Hazardous Substances found at such a facility. CERCLA also authorizes the EPA and, in some cases, third parties to take actions in response to threats to the public health or the environment and to seek to recover the costs of such action. We may also in the future become an owner of facilities on which Hazardous Substances have been released by previous owners or operators. We may in the future be responsible under CERCLA for all or part of the costs to clean up facilities or property at which such substances have been released, and for natural resource damages.
As is true of other regulatory schemes, EPA from time to time suggests changes in CERCLA. Such changes to existing CERLCA regulations may include amendments or additional regulations which will have an economic impact on our operations through increased costs of bonding and reclamation activities. There may be additional legislation or rulemaking related to CERCLA.
Air Emissions
Our operations are subject to state and federal regulations for the control of emissions of air pollution. Major sources of air pollutants are subject to more stringent, federally imposed permitting requirements. Administrative enforcement actions for failure to comply strictly with air pollution regulations or permits are generally resolved by payment of monetary fines and correction of any identified
deficiencies. Alternatively, regulatory agencies could require us to forego construction, modification or operation of certain air emission sources.
Clean Water Act
The Clean Water Act (“CWA”) imposes restrictions and strict controls regarding the discharge of wastes, including mineral processing wastes, into waters of the United States, a term broadly defined. Permits must be obtained to discharge pollutants into federal waters. The CWA provides for civil, criminal and administrative penalties for unauthorized discharges of hazardous substances and other pollutants. It imposes substantial potential liability for the costs of removal or remediation associated with discharges of oil or hazardous substances. State laws governing discharges to water also provide varying civil, criminal and administrative penalties, and impose liabilities in the case of a discharge of petroleum or its derivatives, or other hazardous substances, into state waters. In addition, the EPA and the State of Wyoming have promulgated regulations that require us to obtain permits to discharge storm water runoff. In the event of an unauthorized discharge of wastes, we may be liable for penalties and costs.
Our Employees
At December 31, 2024, Ur-Energy USA had 17 regular full-time employees: six in its Littleton, Colorado office and 11 in its Wyoming offices. At that date, Lost Creek ISR, LLC employed 84 people on a full-time regular basis. Additionally, Ur-Energy USA has three regular part-time employees. None of our other subsidiaries had employees in 2024. Ur-Energy Inc. had no employees during 2024. While we have continued to face challenges of recruitment and retention in hiring for the ramp-up at Lost Creek, we are experiencing stronger retention and are building a core group, including managers, which allows for more complete training and a more robust safety culture. We began hiring for our Shirley Basin project in early 2025.
Corporate Offices
The registered office of Ur-Energy is located at 55 Metcalfe Street, Suite 1300, Ottawa, Ontario K1P 6L5. Our North American Operations Headquarters is located at 1478 Willer Drive, Casper, Wyoming 82604, where our new construction facility and chemical laboratory are now both fully operational. Lost Creek operational offices are located at 3424 Wamsutter / Crooks Gap Road, Wamsutter, Wyoming 82336. Shirley Basin is located at 164 County Road 2, Medicine Bow, Wyoming 82329. Our U.S. Corporate headquarters is located at 10758 West Centennial Road, Suite 200, Littleton, Colorado 80127.
Available Information
Detailed information about Ur-Energy is contained in our annual reports, quarterly reports, current reports on Form 8-K, and other reports, and amendments to those reports that we file with or furnish to the SEC and the Canadian regulatory authorities. These reports are available free of charge on our website, www.ur-energy.com, as soon as reasonably practicable after we electronically file such reports with or furnish such reports to the SEC and the Canadian regulatory authorities. However, our website and any contents thereof should not be considered to be incorporated by reference into this annual report on Form 10-K.
We will furnish copies of such reports free of charge upon written request to our Corporate Secretary:
Ur-Energy Inc.
Attention: Corporate Secretary
10758 West Centennial Road, Suite 200
Littleton, Colorado 80127
Telephone: 1-720-981-4588
Email: legaldept@ur-energy.com
Additionally, our corporate governance guidelines, Code of Ethics and the charters of each of the standing committees of our Board of Directors (“Board”) are available on our website at https://www.ur-energy.com/investors/corporate-governance. We will furnish copies of such information free of charge upon written request to our Corporate Secretary, as set forth as above.
Other information relating to Ur-Energy may be found on the SEC’s website at http://www.sec.gov/edgar.shtml or on the SEDAR website at www.sedarplus.ca.

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ITEM 1A. RISK FACTORS
Item 1A. RISK FACTORS
An investment in our securities involves a high degree of risk. You should consider the following discussion of risks in addition to the other information in this annual report before purchasing any of our securities. In addition to historical information, the information in this annual report contains “forward-looking” statements about our future business and performance. Our actual operating results and financial performance may be very different from what we expect as of the date of this annual report. The risks below address material factors that may affect our future operating results and financial performance.
Risk Factors Related to the Uranium Markets and Nuclear Fuel Cycle Industries
We have entered into term sales contracts for a portion of our Lost Creek and Shirley Basin production; however, we may be unable to enter into additional term sales contracts in the future on suitable terms and conditions.
We have secured term sales contracts for annual base commitments between 440,000 and 1,300,000 pounds U3O8 annually between 2025 and 2030, with at least 100,000 pounds U3O8 committed in each of 2032 and 2033. While we continue to respond to requests for proposals from nuclear fuel purchasers, there is no certainty that we will be able enter additional term sales agreements at suitable pricing and other terms to support longer-term production at Lost Creek and Shirley Basin. The failure to complete additional term sales contracts on suitable terms could adversely impact our operations and resulting cash flows and income.
The uranium market, including the price of U3O8, is volatile and has limited customers.
The price of uranium is volatile and has experienced and may continue to experience significant price movements over short periods of time. Spot pricing reached lows at or below $20 per pound U3O8 in recent years. Although current spot pricing remains significantly improved from those recent lows, pricing continues to demonstrate volatility: at December 31, 2023, the price of U3O8 was $91.00 per pound and at December 31, 2024, the price was $72.63 per pound U3O8. Factors beyond our control affect the market, including demand for nuclear power; changes in public acceptance of nuclear energy; political and economic conditions in uranium mining, producing and consuming countries; costs and availability of financing of nuclear plants; changes in governmental regulations; global or regional consumption patterns; speculative activities and increased production due to new extraction developments and improved production methods; the future viability and acceptance of small modular reactors or micro-reactors and the related fuel requirements for this new technology; reprocessing of spent fuel and the re-enrichment of depleted uranium tails or waste; and global economics, including currency exchange rates, interest rates and expectations of inflation. Any future accidents, or threats of or incidents of war, civil unrest or terrorism, at nuclear facilities are likely to also impact the conditions of uranium mining and the use and acceptance of nuclear energy. The effect of these factors on the price of uranium, and therefore on the economic viability of our properties, cannot accurately be predicted.
The uranium industry is highly competitive and nuclear energy competes with other energy sources.
The national and international uranium industry is small and highly competitive. Our activities are directed toward the exploration for, and evaluation, acquisition and development of uranium deposits into production operations. There is no certainty that any expenditures we made will result in discoveries of commercial quantities of uranium production. There is aggressive competition within the uranium mining industry for the discovery, acquisition and development of properties considered to have commercial potential. We compete with other companies for the opportunity to participate in promising projects, and many of those competing entities have greater financial resources than we have and/or are state-sponsored entities. Similarly, we market our product to a limited number of purchasers in competition with supplies from a very limited number of competitors, most of whom currently are state-sponsored operations producing at lower, subsidized costs.
Nuclear energy competes with other existing sources of energy, including natural gas, oil, coal, hydroelectricity and renewable energy sources and potentially other sources of energy, such as fusion, in the future. These other energy sources are to some extent interchangeable with nuclear energy, and their relative availability and cost may result in lower demand for uranium concentrate and uranium conversion services. Technical advances in and government support and subsidies for renewable energy sources could make these forms of energy more viable and have a greater impact on nuclear fuel demands. Further, the sustained growth of the uranium and nuclear power industry beyond its current level will depend upon continued and increased acceptance of nuclear technology as a means of generating electricity. Because of unique political, geopolitical, technological and environmental factors that affect the nuclear industry, the industry is subject to public opinion risks which could have an adverse impact on the demand for nuclear power, whether through increased regulation or otherwise.
Requirements for our products and services may be affected by technological changes in nuclear reactors, enrichment, and used uranium fuel reprocessing. These technological changes could reduce, or increase, the demand for uranium. The cost competitiveness of our operations may be impacted through development of new uranium recovery and processing technologies. As a result, our competitors may adopt technological advancements that provide them an advantage over our operational and production costs.
Lack of acceptance of, or outright opposition to, nuclear energy could impede our business.
Our future business prospects are tied to the electrical utility industry in the U.S. and worldwide. Continuing fundamental changes in the utility industry, particularly in the U.S. and Europe, are expected to affect the market for nuclear and other fuels for years to come and may result in a wide range of outcomes, including the expansion or the premature shutdown of nuclear reactors. Maintaining the demand for uranium at current levels and future growth in demand will depend upon the continued acceptance of nuclear technology as a means of generating electricity. Unique political and public perception factors impact the nuclear fuel cycle industries, including uranium producers. Some government entities and non-governmental organizations continue to aggressively oppose certain mining activities including specifically uranium recovery. These actions may affect our operations even if the opposition is directed at entities or projects unrelated to our Company. Lack of continued public acceptance of nuclear technology would adversely affect the demand for nuclear power and potentially increase the regulation of the nuclear power industry. Following the events of March 2011 in Fukushima Japan, worldwide reaction called into question the public’s confidence in nuclear energy and technology, and the impact continues in many countries. Additionally, media coverage about uranium production and nuclear energy may be inaccurate or non-objective and further negatively impact public perception of our industry.
Our business is subject to extensive environmental and other regulations that may make exploring, mining or related activities increasingly expensive, and may change at any time.
The mining industry is subject to extensive environmental and other laws and regulations, which may change at any time. Environmental legislation and regulation continue to evolve in ways which may require stricter standards and enforcement, increased fines and penalties for non-compliance, more stringent environmental assessments of proposed projects, increased reclamation obligations and attendant costs (and costs of bonding), and a heightened degree of responsibility for companies and their officers, directors and employees. Various regulatory actions related to the protection of the greater sage grouse, for example, are ongoing. Recurring consideration of additional EPA rulemakings, CERCLA revisions and other changes and further restrictions, including within the regulations promulgated pursuant to the General Mining Law, could have significant impact on our operations and other mineral projects. Moreover, compliance with environmental quality requirements, reclamation laws and other restrictions imposed by federal, state and local authorities may require significant capital outlays and consume additional staff and management time, materially affect the economics of a given property, cause material changes or delays in intended activities, and potentially expose us to litigation and other legal or administrative proceedings. We cannot accurately predict or estimate the impact of any such future laws or regulations, or future interpretations of existing laws and regulations, on our operations. Historic exploration activities have occurred on many of our properties, and mining and energy production activities have occurred on or near certain of our properties. If such historic activities have resulted in releases or threatened releases of regulated substances to the environment, or historic activities require remediation, potential liability may exist under federal or state remediation statutes for which we may be inadequately bonded or insured.
Risk Factors Related to our Mining Operations
Operational and related challenges may continue as we return to steady-state commercial operations at Lost Creek and build out Shirley Basin for production operations.
Challenges have been encountered in our return to commercial production operations at Lost Creek. The extended time the site was maintained on reduced production operation, the required operational refinements and maintenance as operations were restarted, and other commissioning issues have caused delays in achieving production rates on the planned schedule. Challenges with recruitment, training and retention of staff were also experienced. These challenges may continue at Lost Creek until steady-state full rates of production are reached and maintained. As we build out Shirley Basin, we may encounter delays in construction, availability of materials and equipment, labor and contractor availability on a timely basis and other construction and ramp-up challenges. Continuing challenges in operations at Lost Creek and delays, cost overruns or operational challenges at Shirley Basin could affect our ability to achieve our production plans, and timely deliveries of contractual commitments to our customers, thereby negatively affecting our business, financial condition, results of operations and cash flow.
Our mining operations involve significant hazards and risks and the possibility of uninsured losses.
Mining operations generally involve a high degree of risk. We continue operations at our first and, currently, only, uranium in situ recovery facility at Lost Creek, where we began ramp-up to renewed commercial operations in 2023. Lost Creek is a remote site in
south-central Wyoming. Lost Creek, Shirley Basin, and our other projects as they continue in development, will be subject to all the hazards and risks normally encountered at remote mining and work sites in Wyoming, including safety in commuting and severe weather which can affect such commutes and may slow operations, particularly during adverse winter weather and road conditions. Additionally, these operations are subject to perceived risks, and the hazards and risks normally encountered in the production of uranium by in situ methods of recovery, such as water management and treatment, including wastewater disposal capacity (deep wells, Class V wells, ponds or other methods; each of which requires regulatory authorizations and varying levels of expense to install and operate), unusual and unexpected geological formations, unanticipated metallurgical difficulties, equipment malfunctions and availability of materials and parts for operations and construction, interruptions of electrical power and communications, other conditions involved in the drilling and removal of material through pressurized injection and production wells, radiation safety, transportation and industrial accidents, and natural disasters (e.g., fire, tornado), any of which could result in damage to, or destruction of, production facilities, or other property, personal injury or death, environmental damage and possible legal liability. We may also not be insured against all interruptions to our operations. Losses from these or other events may cause us to incur significant costs which could materially adversely affect our financial condition and our ability to fund activities on our properties. A significant loss could force us to reduce or suspend our operations and development. Adverse effects on operations and/or further development of our projects could also adversely affect our business, financial condition, results of operations and cash flow.
Our mineral resource estimates may not be reliable and are inherently more uncertain than estimates of proven and probable reserves. There is risk and increased uncertainty to commencing and conducting production without established mineral reserves.
Our properties do not contain mineral reserves as defined under SEC Subpart 1300 of Regulation S-K (“S-K 1300”) or Canadian National Instrument 43-101 (“NI 43-101”). See “Cautionary Note Concerning Disclosure of Mineral Resources,” above. Until mineral reserves or mineral resources are mined and processed, the quantity of mineral resources and grades must be considered as estimates only and may be inaccurate. We have established the existence of uranium resources for certain uranium projects, including at the Lost Creek Property. We have not established proven or probable reserves, as defined under S-K 1300 or NI 43-101, through the completion of a feasibility study for any of our uranium projects, including the operating Lost Creek Project. Furthermore, we currently have no plans to establish proven or probable reserves for any of our uranium projects for which we plan to utilize ISR methods, such as Lost Creek and Shirley Basin. As a result, and despite the fact that we have produced U3O8 at the Lost Creek Project since 2013, there is increased uncertainty and risk that may result in economic and technical failure which may adversely impact our future profitability.
There are numerous uncertainties inherent in estimating quantities of mineral resources, including many factors beyond our control, and no assurance can be given that the recovery of mineral resources, or even estimated mineral reserves, will be realized. In general, estimates of mineral resources are based upon several factors and assumptions made as of the date on which the estimates were determined, including (i) geological and engineering estimates that have inherent uncertainties and the assumed effects of regulation by governmental agencies; (ii) the judgment of the geologists, engineers and other professionals preparing the estimate; (iii) estimates of future uranium prices and operating costs; (iv) the quality and quantity of available data and the interpretation of that data; and (v) the accuracy of various mandated economic assumptions, all of which may vary considerably from actual results.
All estimates are, to some degree, uncertain; with in situ recovery, this is due in part to limited sampling information collected prior to mining. For these reasons, estimates of the recoverable mineral resources prepared by different professionals, or by the same professionals at different times, may vary substantially. As such, there is significant uncertainty in any mineral resource estimate and actual deposits encountered and the economic viability of a deposit may differ materially from our estimates.
We are depleting our mineral resources and must develop additional resources to sustain ongoing operations.
We have been in production operations for more than a decade and are depleting the estimated mineral resource at Lost Creek, which remains our only uranium recovery operation until we bring Shirley Basin online. As a result, we must be able to continue to conduct exploration and develop additional mineral resources. During the extended downturn in the uranium market, resulting in our reduced operations at Lost Creek and related conservative preservation of our treasury, we did not pursue exploration for additional mineral resources. Although we intend to reinvigorate those programs, there can be no assurance we will discover additional economic uranium mineral resources to sustain and extend our operations. While there remain large areas of our Lost Creek Project which require additional exploration, we will need to continue to explore all project areas of the Lost Creek Property and our other mineral properties in Wyoming, or acquire additional, known mineral resource properties to replenish our mineral resources and sustain continued operations. We estimate life of mine when we prepare our mineral resource estimates, but such estimates may not be correct.
Our property title and rights may be uncertain and could be challenged.
Although we have obtained title opinions with respect to certain of our properties, there is no guarantee that title to any of our properties will not be challenged or impugned. Third parties may have valid claims underlying portions of our interests. Our mineral properties in the U.S. consist of leases covering state lands, unpatented mining claims and millsite claims, and patented mining claims and lands. Many of our mining properties in the U.S. are unpatented mining claims to which we have only possessory title. Because title to unpatented mining claims is subject to inherent uncertainties, it is difficult to determine conclusively ownership of such claims. These uncertainties relate to such things as sufficiency of mineral discovery, proper posting and marking of boundaries and possible conflicts with other claims not determinable from descriptions of record. The present status of our unpatented mining claims located on public lands allows us the exclusive right to mine and remove valuable minerals. We are allowed to use the surface of the public lands solely for purposes related to mining and processing the mineral-bearing ores. However, legal ownership of the land remains with the U.S. We remain at risk that the mining claims may be forfeited either to the U.S. or to rival private claimants due to failure to comply with statutory and regulatory requirements. Certain of the changes which have been proposed in recent years to amend or replace the General Mining Law, could have an impact on the rights we currently have in our patented and unpatented mining and millsite claims. Similarly, we believe that we have the necessary rights to surface use and access in areas for which we have mineral rights other than pursuant to a federal unpatented mining claim. Those rights may also be challenged, resulting in delay or additional cost to assert and confirm our rights. We have taken or will take appropriate curative measures to ensure proper title to our mineral properties and rights in surface use or access, where necessary and where possible. Additionally, our state leases have fixed terms and, while renewals have historically been granted upon timely application, there is no certainty there will not be changes to rights granted and/or the state lands procedures, either of which could negatively affect our mineral projects.
Our mining operations are subject to numerous environmental laws, regulations and licensing and permitting requirements that can delay production and adversely affect operating and development costs.
Our business is subject to extensive federal, state and local laws governing all stages of exploration, development and operations at our mineral properties, taxes, labor standards and occupational health, mine and radiation safety, toxic substances, endangered species protections, and numerous other matters. Exploration, development, and production operations are also subject to various federal, state and local laws and regulations relating to the protection of the environment. These laws impose high standards on the mining industry, particularly with respect to uranium recovery, to monitor the discharge of wastewater and report the results of such monitoring to regulatory authorities, to reduce or eliminate certain effects on or into land, groundwater, water or air, to progressively restore mine properties, to manage hazardous wastes and materials and to reduce the risk of worker accidents. A violation of any of these laws may result in the imposition of substantial fines and other penalties and potentially expose us to operational restrictions, suspension, administrative proceedings or litigation. Many of these laws and regulations have tended to become more stringent over time, which appears will continue to be the trend in coming years. Any change in such laws or imposition of fines or restrictions in operations as a result of violations could have a material adverse effect on our financial condition, cash flow or results of operations. There can be no assurance that we will be able to meet all the regulatory requirements in a timely manner or without significant expense or that the regulatory requirements will not change to delay or prohibit us from proceeding with certain exploration, development or operations. There is no assurance that we will not face new challenges by third parties to regulatory decisions when made, which may cause additional delay and substantial expense, or may cause a project to be permanently halted. Certain recent judicial decisions affecting agency decisions and Administrative Procedures Act precedents, as well as recent agency actions and the significant restrictions proposed by the current U.S. federal administration related to agency staffing and permitting procedures and timelines all are an evolving landscape and create uncertainty and possible additional cost, delays, litigation and negative effects for our business and operations.
Our operations require licenses and permits from various governmental authorities. We believe we hold all necessary licenses and permits under applicable laws and regulations to carry on the activities which we are currently conducting and hold or are pursuing such licenses and permits for activities which are currently proposed, with reasonable expectations of timely receipt. Such licenses and permits are subject to changes in regulations and changes in various operating circumstances. There can be no guarantee that we will be able to timely obtain all necessary licenses and permits that may be required to maintain our exploration and mining activities (or amendments to extend, expand or alter existing operations), including constructing mines, milling or processing facilities and commencing or continuing exploration or mining activities or operations at any of our properties. The uncertainty of the time for and outcome of regulatory processes has grown substantially as the new administration’s Department of Government Efficiency has begun to eliminate jobs, funding and other resources. In addition, if we proceed to production on any other property or new geologic horizon, we must obtain and comply with permits and licenses which will contain specific operating conditions. There can be no assurance that we will be able to obtain such permits and licenses or that we will be able to comply with any and all such conditions. The ability to timely obtain all required authorizations may become more of an issue with regulatory agencies facing staffing challenges similar to those our
industry is encountering, as experienced staff retire or leave government, including those with highly specialized knowledge specific to uranium recovery and radiation safety.
Possible amendments to the General Mining Law could make it more difficult or impossible for us to execute our business plan.
Members of the U.S. Congress have repeatedly introduced bills which would materially amend or replace the provisions of the General Mining Law. Such bills have proposed, among other things, to (i) significantly alter the laws and regulations relating to uranium mineral development and recovery from patented or unpatented mining claims; (ii) impose a federal royalty on production from unpatented mining claims and/or impose other taxes or additional fees on the use or occupancy of federal lands; (iii) impose time limits on the effectiveness of plans of operation that may not coincide with mine life; (iv) convert in part or in whole the existing land holdings program, requiring unpatented mining claims to be taken to lease in a new program under certain circumstances and imposing other circumstances in which the unpatented mining claim would have to be abandoned; (v) limit the mineral property holdings of any single person or company under various stages from prospecting through operations; (vi) impose more stringent environmental compliance and reclamation requirements on activities on unpatented mining claims; (vii) allow states, localities and Native American tribes to petition for the withdrawal of identified tracts of federal land from the operation of the U.S. mining laws; (viii) eliminate or greatly limit the right to a mineral patent; and (ix) allow for administrative determinations that mining would not be allowed in situations where undue degradation of the federal lands in question could not be prevented. Additionally, there continue to be proposals for withdrawal of federal lands for the purposes of mineral location and development, and the reasons for withdrawals have been increasingly broad.
If enacted, such legislation could, among other effects, change the cost of holding unpatented mining claims or leases or the duration for which the claims or leases could be held without development, and could significantly impact our ability to develop locatable mineral resources on our patented and unpatented mining claims. Although it is impossible to predict what any legislated royalties might be, implementation could adversely affect the potential for development of mineral properties, as well as the economics of existing operating mines. Passage of such legislation could adversely affect our financial performance, if passed, including proposals imposing a royalty or otherwise impacting holding and operational costs of mining claims could render mineral projects or existing mines uneconomic. Although certain of the proposed amendments have included provisions to ‘grandfather’ permitted projects, there is no assurance that any new legislation will contain such provisions or that such legislation will not otherwise have a significant financial impact on our operations and business.
We depend on services of our management and key personnel, contractors and service providers, and the timely availability of such individuals and providers cannot be assured.
Successful implementation of our business plan and operations is dependent upon our management team and experienced staff, some of whom are approaching retirement age. From time to time, we may need to recruit additional qualified employees, contractors and service providers to supplement existing management and personnel and to implement various aspects of our succession planning. We continue to hire and train employees for Lost Creek’s renewed operation and we have begun to hire staff for Shirley Basin. Timely availability and training, strong retention rates of staffing and timely retention of contractors cannot be assured in our industry, many aspects of which are highly specialized. This is particularly true in the current labor markets in which we recruit our employees and contractors, including where we compete with higher paying energy jobs, and because of the remote locations for which employees and contractors are needed. As well, the skilled professionals with expertise in geologic, engineering and process aspects of uranium in situ recovery, radiation safety and other facets of our business are currently in high demand, as there are relatively few professionals with both expertise and experience. The sustained downturn of the uranium production industry in recent years makes these challenges even more pronounced. Even with the return to higher levels of production operations, we will be dependent on the continued service of a relatively small number of key persons, including management, senior professionals and key contractors, the loss of any one or several of whom could have an adverse effect on our business and operations. We do not hold key man insurance in respect of any of our executive officers.
Our results of exploration and ultimate production are highly uncertain.
The exploration for, and development of, mineral deposits involve significant risks which a combination of careful evaluation, experience and knowledge may not eliminate. Few properties which are explored are ultimately developed into producing mines, and for those which are developed, there may be longer timelines, delays and greater than estimated costs to advance to production. Major expenses may be required to establish mineral resources or reserves, to develop metallurgical processes and to construct mining and processing facilities at a site. It is impossible to ensure that our current exploration and development programs will result in profitable commercial operations.
Whether a mineral deposit will be commercially viable depends on many factors, including the attributes of the deposit, such as size, grade and proximity to infrastructure, as well as uranium and gold prices, which are highly cyclical. Government regulations, including regulations relating to prices, taxes, royalties, land tenure, land use, importing and exporting of uranium and environmental protection also are factors in determining commercial viability of a mineral project. The exact effect of these factors cannot be accurately predicted, but the combination of these factors may result in us not receiving an adequate return on invested capital.
Our proprietary data, technology and intellectual property may be compromised or lost, which could result in a decreased competitive advantage and/or loss to the value of such assets.
With the ever-increasing reliance on technology throughout our operations, including developments of proprietary technology and intellectual property by the Company and/or its consultants, risks of theft, appropriation or other loss of such technology and assets and/or our proprietary data pose a risk to our competitive advantage and business and financial results. We take what we believe to be reasonable steps to protect these proprietary technologies and intellectual property, including contractually and by efforts to obtain patents or trade rights where possible, but there can be no assurance that all such measures will be sufficient or successful.
Climate change and climate change legislation or regulations could impact our operations.
Although we play an important role in addressing climate change with our production of uranium to fuel carbon-free nuclear power, we, too, may be subject to risks associated with climate change which could harm our results of operations and increase our costs and expenses. The occurrence of severe adverse weather conditions may have a potentially serious impact on our operations. Adverse weather may result in physical damage to our operations, instability of our infrastructure and equipment, or alter the supply of electricity to Lost Creek or Shirley Basin. Impacts of such events may affect worker productivity at our projects. Should any impacts of climate change be material in nature or occur for lengthy periods of time, our financial condition or results of operations would be adversely affected.
As an ISR uranium producer, we maintain a comparatively light environmental footprint. Nonetheless, certain environmental impacts are inevitable from all mineral exploration and development. U.S., Canadian, and other international legislative and regulatory action intended to ensure the protection of the environment are continually changing and evolving in a manner expected to result in stricter standards, restrictions and enforcement, larger fines and liability, and potentially increased capital expenditures and operating costs. Transitioning our business to meet regulatory, societal and investor expectations may cause us to incur lower economic returns than originally estimated for new projects and development plans of existing operations. While we continue to monitor and assess all new policies, legislation and regulations regarding such matters, we currently believe that the impact of any such legislation on our business is unlikely to be material. We cannot, however, assure that our efforts to mitigate the impact of such laws or regulations will be successful and/or without significant attendant costs.
Risks Factors Related to our Financial Circumstances
The uranium mining industry is capital intensive, and we may be unable to raise necessary funding.
Although we currently have substantial funds on hand, additional funds may be required for working capital and exploration and development activities at our properties including Lost Creek and for the construction and development of Shirley Basin. Potential sources of future funds available to us, in addition to the proceeds from sales of existing inventory and future production, include the sale of additional equity capital, proceeds from the exercise of outstanding convertible equity instruments, borrowing of funds or other debt structures, project financing, or the sale of our interests in assets. Continued volatility in the equity markets, particularly the commodities and energy markets, as well as current interest rates, may increase the costs attendant to either equity or debt financing. There is no assurance that such funding will be available to us to fund continued development or future exploration at Lost Creek or the construction and ramp-up of Shirley Basin. Further, even if such financing is secured, there can be no assurance that it will be obtained on terms favorable to us or will provide us with sufficient funds to meet our objectives, which may adversely affect our business and financial position.
Production, operating and capital cost estimates may be inaccurate.
We prepare estimates of annual and future production, the attendant production and operational costs and required working capital for such levels of production, but there is no assurance that we will achieve those estimates. Additionally, we have estimated and continue to estimate the costs of construction for Shirley Basin, in the current market. These types of estimates are inherently uncertain and may change materially over time. Production and operational cost estimates are affected by changes in production levels and may be affected by continuing inflation and cost-of-goods due to supply chain issues as well as the possible need to utilize a greater level of contractor services if required staffing is unavailable or cannot timely be hired and trained. Availability and consistent pricing of materials
necessary in the installation of wells, surface production equipment, associated infrastructure, chemicals for processing and, expendable materials related to operations can be variable depending on economic conditions locally and worldwide and may force changes in operations and timing of resource production. Under prevailing supply chain and market conditions, this is particularly true. In addition, we rely on certain contractors related to the installation of wells and technical services associated with that installation. Their availability or cost of service can change depending on other local market conditions and may therefore affect the installation and production rates of mining.
Risks Related to our Common Shares
We have never paid dividends and do not currently expect to do so in the near future. Therefore, if our share price does not appreciate, our investors may not realize gains and could potentially lose on their investment in our shares.
We have not paid dividends on our common shares since incorporation and do not anticipate doing so in the foreseeable future. We currently intend to retain all available funds and any future earnings to fund the growth of our business. Payments of any dividends will be at the discretion of our Board after considering many factors, including our financial condition and current and anticipated cash needs. As a result, capital appreciation, if any, of our shares will be an investor’s sole source of gain for the foreseeable future.
Failure to meet the listing maintenance criteria of the NYSE American or the TSX may result in the delisting of our common shares, which could result in lower trading volumes and liquidity, lower prices of our common shares and make it more difficult for us to raise capital.
Our common shares are listed on the NYSE American and the TSX, and we are subject to the continued listing requirements of each exchange, including maintaining certain share prices and a minimum level of shareholder equity. The market price of our common shares has been and may continue to be subject to significant fluctuation. If we are unable to comply with the NYSE American or the TSX continued listing requirements, including the trading price requirements, our common shares may be suspended from trading on and/or delisted from the NYSE American or the TSX, respectively. Although we have not been notified of any delisting proceedings, there is no assurance that we will not receive such notice in the future or that we will be able to then comply with NYSE American and TSX listing requirements. The delisting of our common shares from the NYSE American or the TSX may materially impair our shareholders’ ability to buy and sell our common shares and could have an adverse effect on the market price of, and the efficiency of the trading market for, our common shares. In addition, the delisting of our common shares could significantly impair our ability to raise capital.
Further, if our common shares were delisted from the NYSE American, they might be subject to the so-called “penny stock” rules. The SEC has adopted regulations that define a “penny stock” to be any equity security that has a market price per share of less than $5.00, subject to certain exceptions, such as any securities listed on a national securities exchange. For any transaction involving a “penny stock,” unless exempt pursuant to SEC regulations, the rules impose additional sales practice requirements on broker-dealers, subject to certain exceptions. If our common shares were determined to be a “penny stock,” a broker-dealer may find it more difficult to trade our common shares, and an investor may find it more difficult to acquire or dispose of our common shares on the secondary market. These factors could also significantly negatively affect the market price of our common shares and our ability to raise capital.
The trading price of our common shares may experience substantial volatility.
The market price of our common shares has experienced and may continue to experience substantial volatility that is unrelated to the Company’s financial condition or operations. The trading price of our common shares may also be significantly affected by short-term changes in the price of uranium. The market price of the Company’s securities is affected by many other variables which may be unrelated to our success and are, therefore, not within our control. These include other developments that affect the market for all resource sector-related securities, the breadth of the public market for the shares and the attractiveness of alternative investments; market reaction to the estimated fair value of our portfolio; rumors or dissemination of false information; changes in coverage or earnings estimates by analysts; our ability to meet analysts’ or market expectations; and sales of common shares by existing shareholders. The effect of these and other factors on the market price of the common shares is expected to make the price of the common shares volatile in the future, which may result in losses to investors.
Investors may experience future dilution as a result of additional equity offerings.
To raise additional capital, we may in the future offer additional common shares or other securities convertible into or exchangeable for our common shares at prices that may not be the same as the price per share as the shares an investor has previously purchased, and investors purchasing shares or other securities in the future could have rights superior to those of existing shareholders.
We may be a passive foreign investment company and there may be adverse U.S. federal income tax consequences to U.S. shareholders under the passive foreign investment company rules.
Investors in our common shares that are U.S. taxpayers (referred to as a U.S. shareholder) should be aware that we may be a “passive foreign investment company” (a “PFIC”) for the period ended December 31, 2024, and may be a PFIC in subsequent years. If we are a PFIC for any year during a U.S. shareholder’s holding period, then such U.S. shareholders generally will be subject to a special, highly adverse tax regime with respect to so-called “excess distributions” received on our common shares. Gain realized upon a disposition of our common shares (including upon certain dispositions that would otherwise be tax-free) also will be treated as an excess distribution. Excess distributions are punitively taxed and are subject to additional interest charges. Additional special adverse rules also apply to U.S. shareholders who own our common shares if we are a PFIC and have a non-U.S. subsidiary that is also a PFIC (a “lower-tier PFIC”).
A U.S. shareholder may make a timely “qualified electing fund” election (“QEF election”) or a “mark-to-market” election with respect to our common shares to mitigate the adverse tax rules that apply to PFICs, but these elections may accelerate the recognition of taxable income and may result in the recognition of ordinary income. To be timely, a QEF election generally must be made for the first year in the U.S. shareholder’s holding period in which Ur-Energy is a PFIC. A U.S. shareholder may make a QEF election only if the U.S. shareholder receives certain information (known as a “PFIC annual information statement”) from us annually. A U.S. shareholder may make a QEF election with respect to a lower-tier PFIC only if it receives a PFIC annual information statement with respect to the lower tier PFIC. The mark-to-market election is available only if our common shares are considered regularly traded on a qualifying exchange, which we cannot assure will be the case for years in which it may be a PFIC. The mark-to-market election is not available for a lower-tier PFIC.
We will use commercially reasonable efforts to make available to U.S. shareholders, upon their written request for each year in which the Company may be a PFIC, a PFIC annual information statement with respect to the Company and with respect to each such subsidiary that we determine may be a PFIC.
Special adverse rules that impact certain estate planning goals could apply to our common shares if we are a PFIC. Each U.S. shareholder should consult its own tax advisor regarding the U.S. federal, state and local consequences of the PFIC rules, and regarding the QEF and mark-to-market elections.
General Risk Factors
Inflation and supply chain challenges are likely to continue for the foreseeable future.
While many of the direct impacts to our business arising during the COVID pandemic have decreased substantially, direct and indirect effects continue to be experienced, particularly in supply chain and available labor and contractors. Following the pandemic, the inflationary impacts to the economy have been substantial. These impacts are likely to continue to pose risk to our operations, particularly at our renewed production operations at Lost Creek and as we proceed to construct and operate Shirley Basin.
Our insurance coverage, bonding surety arrangements and indemnifications for our inventory could be insufficient or change in adverse ways in the future.
We currently carry insurance coverage for general liability, property and casualty, directors’ and officers’ liability and other matters. We intend to carry insurance to protect against certain risks in amounts we consider adequate. Certain insurances may be cost prohibitive to maintain, and even if we carried all such insurances, the nature of the risks we face in our exploration and uranium production operations is such that liabilities could exceed policy limits in any insurance policy or could be excluded from coverage under an insurance policy. The potential costs that could be associated with any liabilities not covered by insurance or which exceed insurance coverage, or compliance with applicable laws and regulations, may cause substantial delays or interruption of operations and require significant capital outlays, adversely affecting our business and financial position. We cannot assure that even our current coverages will continue to be available at acceptable cost or that coverage limits will remain at current levels, any of which could result in adverse effects upon our business and financial condition. We may be required to obtain additional types of insurance or increase existing coverage amounts due to changes in regulation of the mining and nuclear fuel cycle industries.
Additionally, we utilize a bonding surety program for our regulatory, reclamation and restoration obligations at Lost Creek and Shirley Basin. Availability of and terms for such surety arrangements may change in the future, resulting in adverse effects to our financial condition. Also, we have contractual arrangements with the licensed uranium conversion facility for weighing and storage of our product inventory. Possible loss of or damage to our inventory may not be fully covered by our agreements, indemnification obligations or
insurance. And, with relation to the conversion facility, the storage arrangements may not be extended indefinitely, creating greater costs or other impact to our product inventory. Any loss or damage of the uranium may not be fully covered or absolved by contractual arrangements with the conversion facility.
We are dependent on information technology systems, which are subject to certain risks, including cybersecurity risks and data leakage risks associated with implementation and integration.
We depend upon information technology systems in a variety of ways throughout our operations. While we have not experienced any material incident, any significant breakdown of those systems, whether through virus, cyber-attack, security breach, theft, or other destruction, invasion or interruption, or unauthorized access to our systems, by employees, others with authorized access to our systems or unauthorized persons, could negatively impact our business and operations. These threats are increasing in number and severity and broadening in type of risk, including recently with the war in Ukraine, the war in the Middle East and other geopolitical tensions and the cyber attacks ongoing in those contexts, which may continue to broaden. To the extent that any cyber-attack or similar security breach results in disruption to our operations, loss or disclosure of, or damage to, our data and particularly our confidential or proprietary information, our reputation, business, results of operations and financial condition could be materially adversely affected. We have implemented various measures to manage our risks related to information technology systems and network disruptions. However, given the unpredictability of the timing, nature and scope of information technology disruptions, we potentially could be subject to production downtimes, operational delays, the compromising of confidential or otherwise protected information, destruction or corruption of data, security breaches, other manipulation or improper use of our systems and networks or financial losses from remedial actions, any of which could have a material adverse effect on our cash flows, competitive position, financial condition or results of operations. Our systems and internal controls for protecting against such cyber security risks may be insufficient and it is increasingly difficult to fully mitigate against these threats as they are ever changing. Additionally, we assess possible threats to our third-party providers when they may be provided confidential and proprietary information to complete work in our behalf. While we seek assurances from those parties that they will maintain such confidential and proprietary information in confidence, including by virtue of having systems and processes in place to protect such data, those service providers may also be subject to data compromise. Any compromise of our confidential data or that of our customers, suppliers, employees or others with whom we do business, whether in our possession or that of our service providers, could substantially disrupt our operations, harm our customers, suppliers, employees and others with whom we do business, damage our reputation, violate applicable law, subject us to potentially significant costs and liabilities which could be material. Although to date we have experienced no such attack resulting in material losses, we may suffer such losses at any time in the future. We may be required to expend significant additional resources to continue to modify and enhance our protective measures or to investigate, restore or remediate any information technology security vulnerabilities.
We may also be adversely affected by system or network disruptions if new or upgraded information technology systems are defective, not installed properly or not properly integrated into our operations. If we are unable to successfully implement system upgrades or modifications, we may have to rely on manual reporting processes and controls over financial reporting that have not been planned, designed or tested. Various measures have been implemented to manage our risks related to the system upgrades and modifications, but system upgrades and modification failures could have a material adverse effect on our business, financial condition and results of operations and could, if not successfully implemented, adversely impact the effectiveness of our internal controls over financial reporting.
We are subject to risks associated with litigation, governmental or regulatory investigations or challenges, and other legal proceedings.
Defense and settlement costs of legal claims can be substantial, even with respect to claims that have no merit. From time to time, we may be involved in disputes with other parties which may result in litigation, arbitration, or other proceedings. Additionally, it is possible that the Company may become involved directly or indirectly in legal proceedings, in the form of governmental or regulatory investigations, administrative proceedings or litigation, arising from challenges to regulatory actions. Such investigations, administrative proceedings and litigation related to regulatory matters may delay or halt exploration, development or even operations at our projects. The results of litigation or any other proceedings cannot be predicted with certainty. If we are unable to resolve any such dispute favorably, it could have a material adverse effect on our financial position, results of operations or our property development.
We may develop conflicts of interest with other mining or natural resource companies with which one of our directors may be affiliated. Our directors may allocate their time to other businesses thereby causing conflicts of interest in their determination as to how much time to devote to our affairs.
Certain of our directors are also directors of other companies that are engaged in similar mining or natural resources businesses, namely the acquisition, exploration, and development of mineral properties. Such other associations may give rise to conflicts of interest from
time to time. One of the possible consequences will be that corporate opportunities presented to a director may be offered to another company with which the director is associated and may not be made available to us. Conflicts of interest may also include decisions on how much time to devote to the business of our company. Our Code of Business Conduct and Ethics provides guidance on conflicts of interest and our directors are required to act in good faith, to make certain disclosures and to abstain from voting on decisions in which they may have a conflict of interest.
Acquisitions and integration may disrupt our business, and we may not obtain full anticipated value of certain acquisitions due to the condition of the markets.
From time to time, we examine opportunities to acquire additional mining assets and businesses. Any acquisition that we may choose to complete may be of significant size, may change the scale of our business and operations, and/or may expose us to new geographic, political, operating, financial and geological risks. Any acquisition would be accompanied by risks, including (i) a significant change in commodity prices after we commit to complete a transaction and establish the purchase price or share exchange ratio; (ii) a material mineral deposit may prove to be below expectations; (iii) difficulty integrating and assimilating the operations and personnel of an acquired company, realizing anticipated synergies and maximizing the financial and strategic position of the combined enterprise, and maintaining uniform standards, policies and controls across the organization; (iv) the integration of the acquired business or assets may disrupt our ongoing business and relationships with employees, customers, suppliers and contractors; and (v) the acquired business or assets may have unknown liabilities which may be significant. There can be no assurance that we would be able to conclude any acquisition successfully, or that we would be successful in overcoming these risks or other problems encountered in connection with such an acquisition.
Global conflicts and geopolitics continue to have implications to the global economy and energy supplies; as a result, the impact to the nuclear fuel market remains uncertain.
The global implications of the war in Ukraine remain difficult to predict. The war has resulted in impacts to the nuclear fuel industries and uranium producers through the imposition of sanctions and counter sanctions, and more may follow. The war is likely to continue to have an adverse effect on energy and economic markets, including the nuclear fuel industries, because of the vast reliance by the U.S. and other nations on uranium products exported from Russia and Russian-controlled or influenced sources.
The conflicts in the Middle East, and other geopolitical tensions, including between the U.S. and China, also make it difficult to assess and predict the impact to the economy, supply and trade disruption and increased prices of materials, and cyber-security threats. While we do not currently purchase goods and materials directly from China for our Lost Creek operations, our suppliers of electronics and instrumentation components may purchase necessary materials from China, and we may be indirectly affected if the market for Chinese products is further disrupted by sanctions, countersanctions or other events. As we continue with the construction and development of Shirley Basin, the direct or indirect exposure to these market uncertainties may be greater or more direct. Recent international trade issues, including tariffs and counter tariffs, if continued, may also have a negative impact on our operations, construction of Shirley Basin and on our business generally.
To the extent these conflicts and geopolitical situations adversely affect our business as discussed, they may also have the effect of heightening many of the other risks described in this Item 1A such as those relating to cyber-security, supply chain, inflationary and other volatility in prices of goods and materials, and the condition of the markets including as related to our ability to access additional capital, any of which could negatively affect our business. Because of the highly uncertain and dynamic nature of the wars in Ukraine and the Middle East, global conflicts and related geopolitics, it remains difficult to estimate the impact on our business.
Changing global and regional political and economic conditions could adversely impact our business.
Recent political and economic shifts, both domestic and international, may create uncertainty and pose risks to our operations and business. Government policies related to protectionism, economic nationalism and attitudes toward multinational corporations could result in regulatory changes, trade barriers, or investment restrictions. Additionally, international trade disputes - including tariffs, counter-tariffs, export controls, sanctions and currency regulations - may increase costs, further disrupt supply chains, and have other negative impacts on our business and operating models. Furthermore, market volatility, driven by shifts in US and foreign trade policies, fluctuating interest rates or currency controls, may affect commodity prices, capital availability and investor confidence. Even the perception of these risks could lead to reduced investment, higher production and operating costs, and other operational challenges. If such trends continue, they may have a material adverse effect on our business and financial performance; it is difficult to estimate the impact on our business. To the extent these conditions adversely affect our business as discussed, they may also have the effect of heightening many of the other risks described in this Item 1A such as those relating to cyber-security, supply chain, inflationary and
other volatility in prices of goods and materials, and the condition of the markets including as related to our ability to access additional capital, any of which could negatively affect our business.

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ITEM 1B. UNRESOLVED STAFF COMMENTS
Item 1B. UNRESOLVED STAFF COMMENTS
None.

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ITEM 2. PROPERTIES

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ITEM 3. LEGAL PROCEEDINGS
Item 3. LEGAL PROCEEDINGS
None.

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ITEM 4. MINE SAFETY DISCLOSURE
Item 4. MINE SAFETY DISCLOSURE
Our operations and other activities at Lost Creek are not subject to regulation by the Federal Mine Safety and Health Administration (“MSHA”) under the Federal Mine Safety and Health Act of 1977 (the “Mine Act”).
PART II

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ITEM 5. MARKET FOR REGISTRANT'S COMMON EQUITY
Item 5. MARKET FOR REGISTRANT’S COMMON EQUITY, RELATED STOCKHOLDER MATTERS AND ISSUER PURCHASES OF EQUITY SECURITIES
Market Information
Since July 24, 2008, Ur-Energy’s Common Shares have been listed for trading on the NYSE American exchange under the trading symbol “URG.” Since November 29, 2005, Ur-Energy’s Common Shares have been listed and posted for trading on the Toronto Stock Exchange under the trading symbol “URE.”
Holders
The authorized capital of Ur-Energy consists of an unlimited number of Common Shares and an unlimited number of Class A Preference Shares. As of April 9, 2025, we had 364,819,260 Common Shares issued and outstanding; no preferred shares are issued and outstanding. We estimate that we have approximately 6,700 beneficial holders of our Common Shares. The holders of the Common Shares are entitled to one vote per share at all meetings of our shareholders. The holders of Common Shares are also entitled to dividends, if and when declared by our Board and the distribution of the residual assets of the Company in the event of a liquidation, dissolution or winding up.
Our Class A Preference Shares are issuable by the Board in one or more series and the Board has the right and obligation to fix the number of shares in, and determine the designation, rights, privileges, restrictions and conditions attaching to the shares of, each series. The rights of the holders of Common Shares will be subject to, and may be adversely affected by, the rights of the holders of any Class A Preference Shares that may be issued in the future. The Class A Preference Shares, may, at the discretion of the Board, be entitled to a preference over the Common Shares and any other shares ranking junior to the Class A Preference Shares with respect to the payment of dividends and distribution of assets in the event of liquidation, dissolution or winding up.
Dividends
To date, we have not paid any dividends on our outstanding Common Shares and have no current intention to declare dividends on the Common Shares in the foreseeable future. Any decision to pay dividends on our Common Shares in the future will depend upon our financial requirements to finance future growth, the general financial condition of the Company and other factors which our Board may consider appropriate in the circumstances.
Recent Sales of Unregistered Securities
During the fiscal years ended December 31, 2024 and 2023 we did not have any sales of securities in transactions that were not registered under the Securities Act.
Issuer Purchases of Equity Securities
The Company did not purchase its own equity securities during the fiscal year ended December 31, 2024.

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ITEM 6. SELECTED FINANCIAL DATA
Item 6. RESERVED

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ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS
Item 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATION
Business Overview
The following discussion is designed to provide information that we believe necessary for an understanding of our financial condition, changes in financial condition and results of our operations. The following discussion and analysis should be read in conjunction with the accompanying audited consolidated financial statements and related notes. The financial statements have been prepared in accordance with US GAAP.
Industry and Market Update
Recognition of the critical role nuclear energy plays in providing baseload power for decarbonization has been complemented more recently as energy security has become a universal priority. Energy security includes not only the heightened concern over Russian supply, but other areas of geopolitical unrest. Throughout 2024, both U.S. and non-U.S. utilities increasingly sought non-Russian supplies when negotiating uranium term sales agreements. This change of supply priority reflects the concern over existing and possible additional sanctions as well as the prospect that Russia of its own volition will refuse to export committed nuclear fuels to the U.S. In either circumstance, the utilities remain at significant risk as the West has limited capacity to backfill such supply disruption, regardless of cause.
In the U.S., the ban on Russian imports of nuclear fuels, signed into law earlier in the year, became effective in August 2024. While allowing certain waivers until January 1, 2028, the prohibitions on imports continue through 2040. The ban will help to secure the U.S. nuclear fuel supply chain and advance domestic uranium recovery operations.
The effects of geopolitical tensions beyond Russia will continue to have a role in the nuclear fuel cycle industries. The true scope and possible long-standing impact of China in the nuclear market remains undefined.
The nuclear markets have been favorably affected in many ways through greater acceptance of nuclear energy. Recently, technology and other industries operating data centers (in what is now simply being referred to as “big data”) have realized the opportunities which exist to maintain carbon free baseload electricity while supporting the immense electric demand generated by these centers. The Electric Power Research Institute’s May 28, 2024, white paper titled Powering Intelligence, suggests that data centers are expected to consume as much as 9.1% of U.S. electricity generation by 2030 compared with an estimated 4% today. It is further estimated that, globally, data centers will drive electricity demand in many regions. Projections suggest that 2026 electricity consumption for data centers alone will be the equivalent of the electricity consumption of Japan.
Several significant power purchase agreements have been announced in recent months, including the largest-ever purchase agreement by Constellation Energy to power data centers owned by Microsoft for 835 megawatts of electricity. This agreement will result in the restart of the Three Mile Island Unit 1 nuclear reactor in Pennsylvania. While contributing 835 megawatts of carbon-free electricity to the grid, this historic project will create 3,400 jobs and offset approximately 61 million metric tons of CO2 emissions over 20 years. Still others in big data, including Google and Amazon, have announced plans to utilize nuclear energy to satisfy these rapidly growing electrical needs.
The U.S. Department of Energy (DOE) has been progressing its requests for proposals under both its high-assay, low-enriched uranium (HALEU) and low-enriched uranium (LEU) programs for which domestic uranium supply is preferred. In October 2024, the DOE announced it awarded contracts to Centrus Energy Corp., Orano SA, General Matter Inc. and Louisiana Energy Services (a URENCO company) to provide enrichment services to develop HALEU to fuel small modular nuclear reactors. The contracts for enrichment are worth up to $2.7 billion over the next ten years. These programs also reflect efforts by the U.S. to advance energy security; Russia has been the only potential commercial source of HALEU.
The Trump administration has prioritized several initiatives including Executive Orders to increase domestic energy and critical minerals production and strengthen American leadership in Artificial Intelligence (“AI”). AI infrastructure has energy needs that are multiples of traditional data centers. In addition, the Trump administration has noted that it may implement tariffs on certain countries to strengthen border security and address trade deficits which may be beneficial for U.S. uranium producers that intend to supply U.S. utilities. Recently, U.S. Department of Energy Secretary Wright issued a secretarial order titled “Unleashing the Golden Era of American Energy
Dominance.” The order states, in part, “[t]he long-awaited American nuclear renaissance must launch during President Trump’s administration. As global energy demand continues to grow, America must lead the commercialization of affordable and abundant nuclear energy.” Also, in February 2025, the Trump administration, through an Executive Order, established the National Energy Dominance Council which has numerous goals including “bringing Small Modular Reactors online.”
Internationally, support for nuclear power continues to grow with strong support in Spain, Belgium and Switzerland to keep their reactors on-line. There is also a movement within Germany to restart shuttered reactors given the high cost of renewable energy. Many other countries which historically have not been home to nuclear power are considering or moving toward legalizing nuclear power with the goal of building conventional or small modular reactors.
The volatility in the spot market continued throughout 2024. Following earlier increases in uranium market pricing in 2022 and 2023, pricing throughout 2024 retracted. After passing the $100 per pound U3O8 milestone in early 2024, the spot price gradually declined throughout the year to end in the low $70s. In early 2025, spot pricing further retracted to the mid-$60s.
Conversely, after beginning 2024 at $68 per pound, term market prices gradually increased throughout the year to end at $80.50 per pound U3O8. Term prices thus far in 2025 have remained steady.
2024 Developments
Lost Creek Property - Great Divide Basin, Wyoming
Status of Lost Creek
Since commencement of operations at Lost Creek in 2013 through December 31, 2024, we have captured more than 3.0 million pounds of U3O8.
Ramp up continued at Lost Creek in 2024 with six header houses coming online. Most recently, Header House (HH) 2-12 came online in late January 2025 and HH 2-13 was brought online in late March 2025. The average production solution head grade in Q4 2024 was 66.2 mg/L. We captured approximately 81,771 pounds U3O8 in Q4 2024, and a total of 265,746 pounds U3O8 in 2024. We drummed 74,006 pounds U3O8 in Q4 2024 and a total of 249,209 pounds U3O8 in 2024. Pounds captured increased from 103,487 pounds in 2023 to 265,746 pounds in 2024.
Lost Creek Operations
In 2024, wellfield delineation and development continued in MU2, in what is referred to as Phase 2 within MU1 and, most recently, in MU5. All remaining planned production areas of MU2 are expected to come online during 2025 with HHs 2-12 and 2-13 online in Q1 and HHs 2-14 and 2-15 expected to begin operation in Q2 2025. HH 2-14 is onsite and set on its foundation, with construction underway (basement piping, pipeline, electrical connections, etc.). During the latter half of 2025, we anticipate bringing several header houses online in MU1 Phase 2 as we advance toward full plant capacity production. The first of those header houses (1-14 and 1-15) are awaiting delivery to Lost Creek, and 1-16 is being assembled in our Casper construction facility.
We completed the additional deep disposal well at Lost Creek in 2024 H1 and, following receipt of all regulatory approvals, began operations of the well in early Q4 2024. The deep well is operating as anticipated to complement the other wastewater disposal systems at Lost Creek.
The restart at Lost Creek has encountered challenges. Commissioning new production areas and recommissioning plant operations, not unexpectedly, come with unique start-up issues. The recovery of U3O8 in MU2 and the restart of plant operations have been no exception. As the plant was being recommissioned, we encountered equipment issues that temporarily stalled plant throughput.
During 2024, we continued to encounter staffing issues, including lower than preferred retention rates, which affected our ability to thoroughly train our teams. Lost Creek’s staff of approximately 75 onsite and six staff members in Casper, is largely complete, and, more recently, we are experiencing stronger retention, which facilitates more thorough training. As our growing core staff have more time on the job, we are seeing steady improvement in production activities.
Our drill contractors now have 21 drill rigs at Lost Creek, with the most recent addition mobilized in February 2025. We anticipate that this number is sufficient for Lost Creek drill programs in 2025, including our planned exploration program.
We continue to benefit from our advance ordering and recycling of equipment at Lost Creek while supply chain issues continue. All construction materials are ordered for planned operations months in advance. Parts and materials are always in various stages of delivery depending on availability. We will continue to supplement purchases with recycled materials as necessary.
Lost Creek Regulatory Proceedings
The first two mine units at Lost Creek have all permits necessary for commercial level operations. We have received Wyoming Uranium Recovery Program (“URP”) approval of the amendment to the Lost Creek source material license to include recovery from the LC East Project (HJ and KM horizons) immediately adjacent to the Lost Creek Project and additional HJ horizons at the Lost Creek Project. This license approved access to six planned mine units in addition to the already licensed three mine units at Lost Creek. The approval also increased the license limit for annual plant production to 2.2 million pounds U3O8 which includes wellfield production of up to 1.2 million pounds U3O8 and confirmed toll processing up to one million pounds U3O8.
We anticipate the Wyoming Department of Environmental Quality (“WDEQ”), Land Quality Division (“LQD) will approve the LC East and KM horizon amendment during H1 2025. The amendment adds HJ and KM geological horizons within the area that is immediately adjacent to the existing permit and provides for an additional mine unit in the HJ geological horizon for the existing permitted area. Water Quality Division (“WQD”) continues to work with EPA toward the issuance of the required aquifer exemption for the expanded area. We anticipate that all approvals will be received on a timely basis for our current production plans.
Our request for extension of our Lost Creek source material license was submitted in 2021. The license renewal is in timely review and continues to proceed through the technical review with URP.
2024 Purchases and Sales of U3O8 and Sales Projections for 2025
As projected, during 2024, we sold 570,000 pounds U3O8 of which 395,000 pounds U3O8 were sold in Q4 2024. We received sales proceeds of $33.1 million for the 570,000 pounds U3O8 sold.
To establish a strong product inventory, we purchased 300,000 pounds U3O8 in Q4 2024 at an average cost of $80.61. Additionally, we secured an inventory loan facility under which we borrowed 250,000 pounds U3O8 in December 2024. These transactions facilitated a timely delivery into our sales commitments in Q4 2024. We anticipate that having these pounds in inventory will allow us to cover any further delays in production ramp up and to make deliveries when there is simply a shortfall due to the timing of scheduled delivery dates in a given delivery year.
We have reached agreement to defer the anticipated 2025 delivery of 300,000 pounds U3O8 into 2026 H1, after which our sales in 2025 are projected to be 440,000 pounds U3O8 into our sales agreements.
Sales Agreements
Beginning in 2022, we have secured seven multi-year sales agreements with global nuclear purchasers. Of these, we completed three new agreements in 2024, including a sales agreement signed in February 2024 for annual delivery of between 100,000 and 350,000 pounds U3O8 over a five-year period beginning in 2026. The agreement includes the opportunity for the purchaser to add up to three additional annual deliveries of 300,000 pounds U3O8 beginning in 2031. The pricing for the sales under this agreement is a combination of an escalated fixed price, which is well above the anticipated all-in costs of production, and market related pricing that is subject to an escalated floor and ceiling. The purchaser has the option of a small flex to the annual delivery.
In April 2024, we executed an additional sales agreement which calls for annual delivery commitments of up to 100,000 pounds U3O8 in 2026 through 2029, a portion of which is based upon production milestones. Pricing is a combination of escalated fixed price, well above anticipated all-in costs of production, and a market-related pricing component that is subject to an escalated floor and ceiling. We have provided notice to the buyer of satisfaction of the milestones related to the 2026 and 2027 deliveries.
In November 2024, we completed an additional sales agreement which calls for deliveries of 100,000 pounds U3O8 in each of 2029, 2032 and 2033, and a delivery of 150,000 pounds U3O8 in 2030. Pricing is a combination of market related pricing subject to floor and ceiling parameters escalated annually, and a base escalated fixed price. Pricing is well above our anticipated all-in costs of production.
We have seven off take sales agreements with various global nuclear purchasers which provide for deliveries between 2025 and 2033 as follows:
Base Quantity
Year
(U3O8 Pounds)
440,000
1,250,000
1,150,000
1,300,000
800,000
700,000
-
100,000
100,000
5,840,000
Shirley Basin Project
Based on our contract book and the state of the market generally, early in 2024, we announced a “go” decision to begin buildout of our Shirley Basin in situ recovery facility in Carbon County, Wyoming. Thereafter, we initiated several work programs for the year which complemented our initial purchasing plan for long lead-time equipment which began in 2023.
Installation of 125 monitor wells at Shirley Basin was completed in 2024 including the 98 wells required for the first mine unit at Shirley Basin (SBMU1). Hydrologic testing for the SBMU1 newly installed monitor wells yielded excellent results that are consistent with historic test results. Twenty-five other monitor wells were installed to enhance operational readiness, including seven injection and production pattern test wells. Installation of downhole pumps in the monitor wells will begin in H1 2025 allowing baseline sampling to be completed. Installation of SB MU1 production wells will begin in Q2 2025 utilizing approximately six drill rigs. Construction of SBMU1 wellfield infrastructure (e.g., pipelines, powerlines and field access roads) is expected to begin in Q2 2025. Fabrication of header houses in our Casper construction shop will commence mid-year as well.
Subsequent to year-end, we initiated production and injection testing of representative wells in Mine Unit 1 to facilitate better engineering of pumping and pipeline systems. The related analyses are ongoing. Tests to date indicate that flow rates are high. We expect flow rates will vary throughout the project but the production rates in the individual test pattern wells are within the range of 70 to 80 gpm. These rates are consistent with the high historic inflow of water into the underground workings at Shirley Basin in the early 1960s that drove innovation toward in situ mining at the project and resulted in the recovery of 1.5 million pounds of U3O8 through ISR, before other mining methods were initiated.
The existing south access road to the site has been upgraded to an all-season road. Power supply to the satellite plant construction area has been completed and the line is energized. The septic system is installed. Construction of fifteen IX columns remains on target with delivery expected in Q3 2025. Our purchasing program for equipment and long-lead time items such as ion exchange resin continues, with an emphasis on continually reviewing and acting on purchases of long lead-time items such as electronic components. The local power company is upgrading and refurbishing the existing electrical substation with the goal of completing the upgrade in Q4 2025 prior to commencement of production operations. A backup trailer-mounted substation is available if the work is not timely completed.
Initial plans to construct new offices and shops were revised in favor of installing modular offices and utilizing existing buildings for shops. Renovations of existing site buildings which will be used for construction, maintenance and drill casing facilities are substantially complete. The office building layout has been approved the modular office space will be approximately 2,400 square feet. The building is anticipated to be delivered in Q3 2025. Additional modular office and facility buildings have been purchased and are on site at Shirley Basin.
Engineering related to the satellite plant, including the wastewater treatment system, is nearing completion and the selection process of construction contractors is well underway. We continue to expect construction at Shirley Basin to be complete in late 2025 with a pre-operation inspection by the State of Wyoming following soon after.
Drilling and wellfield development is scheduled to begin in Q2 2025, with an anticipated six drill rigs onsite for the 2025 program. Delineation and exploration drilling were completed historically, and initial detailed wellfield, pipeline and header house layouts have been finalized. Procurement of equipment and materials required for trunkline piping from the wellfield to the plant site has begun and staff are installing the necessary monitor well sampling equipment to support that next phase of work.
We have begun hiring Shirley Basin management and construction and development staff. Additional staff will be hired along a planned schedule throughout the year in order to allow time for task and safety training.
Shirley Basin is fully permitted and licensed, with all major regulatory approvals for construction. The project has a licensed wellfield capacity of one million pounds U3O8 per year. The Company plans three relatively shallow mining units at the project, where we plan to construct a satellite plant, from which loaded resin will be sent to Lost Creek for processing. The annual production of U3O8 from wellfield production and toll processing of loaded resin or yellowcake slurry will not exceed two million pounds equivalent of dried U3O8 product.
Corporate Developments
Equity Financing
On July 29, 2024, the Company closed an underwritten public offering of 57,150,000 common shares at a price of $1.05 per common share. The Company also granted the underwriters a 30-day option to purchase up to 8,572,500 additional common shares on the same terms. The option was exercised in full. Including the exercised option, Ur-Energy issued a total of 65,722,500 common shares. The gross proceeds to Ur-Energy from this offering were approximately $69.0 million. After fees and expenses of $3.8 million, net proceeds to the Company were approximately $65.2 million.
Prepayment of State Bond Loan
On February 29, 2024, we provided notice to Sweetwater County, Wyoming, the Wyoming State Treasurer and the Trustee of our intention to prepay all remaining amounts on the State Bond Loan on April 1, 2024. We completed the pre-payment of the remaining $4.4 million on our State Bond Loan on March 27, 2024.
Senior Management and Changes in Board Composition
In March 2024, we expanded our executive team with the appointment of Ryan Schierman as our Vice President Regulatory Affairs. Prior to joining Ur-Energy, Mr. Schierman held numerous positions in management, most recently at Fluor/Idaho Environmental Coalition, contractors to the U.S. Department of Energy, at the Idaho Cleanup Project. Mr. Schierman has also held several positions in the uranium recovery industry, gaining expertise in regulatory relations and compliance, licensing, and environmental health and safety. As the Wyoming Uranium Recovery Program Manager (2015-2020), Mr. Schierman was critical in assisting Wyoming to become the 38th US Nuclear Regulatory Commission Agreement State. Mr. Schierman earned a B.S. in Environmental Science from Brigham Young University, a M.Sc. in Health Physics from Idaho State University, and is a Certified Health Physicist.
In April 2024, we announced the appointment of John Paul Pressey and Elmer W. Dyke as new members of the Ur-Energy Board of Directors. And, following the Company’s Annual Meeting of Shareholders, June 6, 2024, founding Director James M. Franklin and Director, and former President and CEO, W. William Boberg both retired.
John Paul Pressey had a nearly three-decade long career in the assurance practice at PricewaterhouseCoopers LLP, with 16 years as a partner. With a Bachelor of Commerce degree from the University of Alberta, Mr. Pressey is a Chartered Professional Accountant with extensive experience working with U.S. and Canadian publicly traded companies in the mining industry, and other industries including manufacturing, utilities, and alternative energy. His experience includes acquisitions and capital markets transactions, working with clients to identify and implement practical business solutions to accounting, audit and financial issues. Mr. Pressey spent six years at PricewaterhouseCoopers as its Assurance Leader for British Columbia, overseeing all aspects of PricewaterhouseCoopers’s assurance results and operations for that Province.
Elmer Dyke has over 25 years’ experience in the commercial and government nuclear industry. Mr. Dyke has a Bachelor of Arts Degree in International Political Economy from Davidson College and served as a U.S. Army Officer for 13 years. Mr. Dyke’s professional career includes a tenure with the U.S. Department of State during which he directed international security programs, including nuclear nonproliferation and high technology projects and was detailed to the Departments of Defense and Commerce. Mr. Dyke has worked within global firms NAC International and Booz Allen Hamilton where he served as an expert on nuclear nonproliferation, strategy and
nuclear fuel cycle. More recently, Mr. Dyke filled senior executive roles at Centrus Energy Corporation, a global nuclear fuel supplier and technical services provider. At Centrus Energy and in prior executive roles, Mr. Dyke led strategic planning and business development, financial performance, and risk management for the businesses. Currently, Mr. Dyke leads New Horizons Nuclear Associates, LLC, a global nuclear consulting firm he formed in 2021.
Results of Operations
Reconciliation of Non-GAAP measures with US GAAP financial statement presentation
The following tables include measures specific to U3O8 sales, product cost, product profit, pounds sold, price per pound sold, cost per pound sold, and product profit per pound sold. These measures do not have standardized meanings within US GAAP or a defined basis of calculation. These measures are used by management to assess business performance and determine production and pricing strategies. They may also be used by certain investors to evaluate performance. The following two tables provide a reconciliation of U3O8 price per pound sold and U3O8 cost per pound sold to the consolidated financial statements.
U3O8 Price per Pound Sold Calculation
Unit
Sales per financial statements
$000
17,679
33,706
Disposal fees
$000
(351)
(560)
U3O8 sales
$000
17,328
33,146
U3O8 pounds sold
lb
280,000
570,000
U3O8 price per pound sold
$/lb
61.89
58.15
Sales per financial statements includes U3O8 sales and disposal fees. Disposal fees received at Pathfinder’s Shirley Basin facility do not relate to the sale of U3O8 and are excluded from the U3O8 sales and U3O8 price per pound sold measures.
U3O8 Cost per Pound Sold Calculation
Unit
Cost of sales per financial statements
$000
19,365
42,679
Lower of cost or NRV adjustment
$000
(10,689)
(6,005)
U3O8 product costs
$000
8,676
36,674
U3O8 pounds sold
lb
280,000
570,000
U3O8 cost per pound sold
$/lb
30.99
64.34
Cost of sales per the financial statements includes U3O8 costs of sales and lower of cost or NRV adjustments. U3O8 cost of sales includes ad valorem and severance taxes related to the extraction of uranium, all costs of wellfield and plant operations including the related depreciation and amortization of capitalized assets, reclamation, and mineral property costs, plus product distribution costs. These costs are also used to value inventory. The resulting inventoried cost per pound is compared to the NRV of the product, which is based on the estimated sales price of the product, net of any necessary costs to finish the product. Any inventory value in excess of the NRV is charged to cost of sales in the financial statements. NRV adjustments, if any, relate to U3O8 inventories and do not relate to the sale of U3O8, and are excluded from the U3O8 cost of sales and U3O8 cost per pound sold measures.
U3O8 Product Sales
The following table provides information on our U3O8 product sales.
Unit
U3O8 Product Sales by Product Type
U3O8 Product Sales
Produced
$000
13,670
16,646
Non-produced
$000
3,658
16,500
$000
17,328
33,146
U3O8 Pounds Sold
Produced
lb
223,259
270,000
Non-produced
lb
56,741
300,000
lb
280,000
570,000
U3O8 Price per Pounds Sold
Produced
$/lb
61.23
61.65
Non-produced
$/lb
64.47
55.00
$/lb
61.89
58.15
The Company made the decision to ramp up operations after securing new term contracts in 2022 with initial deliveries beginning in 2023. In 2023, we delivered 280,000 produced pounds into term contracts at an average price per pound sold of $61.89. In 2024, we delivered 570,000 pounds at an average price per pound sold of $58.15.
The higher 2023 price was influenced by the sale of 100,000 pounds into the U.S. Department of Energy (“DOE”) uranium reserve program at $64.47 per pound sold. The lower 2024 price resulted from making a delivery of 300,000 pounds at $55.00 per pound into a sales contract that was executed in 2022 when the long-term price was between $43 and $52 per pound.
U3O8 Product Costs
The following table provides information on our U3O8 product costs.
Unit
U3O8 Product Cost by Product Type
U3O8 Product Cost
Ad valorem and severance taxes
$000
Cash costs
$000
4,153
10,908
Non-cash costs
$000
1,976
2,719
Produced
$000
6,261
13,914
Non-produced
$000
2,415
22,760
$000
8,676
36,674
U3O8 Pounds Sold
Produced
lb
223,259
270,000
Non-produced
lb
56,741
300,000
lb
280,000
570,000
U3O8 Cost per Pound Sold
Ad valorem and severance taxes
$/lb
0.59
1.06
Cash costs
$/lb
18.60
40.40
Non-cash costs
$/lb
8.85
10.07
Produced
$/lb
28.04
51.53
Non-produced
$/lb
42.56
75.87
$/lb
30.99
64.34
In 2023, we delivered 280,000 produced pounds into term contracts at an average U3O8 cost per pound sold of $30.99. In 2024, we delivered 570,000 pounds at an average U3O8 cost per pound sold of $64.34.
The 2023 sales consisted of 223,259 produced pounds and 56,741 non-produced pounds. The average cost per produced pound sold in 2023 was $28.04. The pounds had been produced years earlier at a lower average cost per pound when the mine was operating at higher, pre-ramp up, production levels. The previously produced pounds were carried in inventory until sold in 2023. During 2022, we purchased 40,000 pounds at $49.50 per pound, which increased the average cost per non-produced pound to $42.56 when we sold the pounds in 2023.
The 2024 sales consisted of 270,000 produced pounds and 300,000 non-produced pounds. The produced pounds were captured and drummed during the ramp up period at a higher average cost per pound when the mine operated at lower, ramp up, production levels. During 2024, we purchased 300,000 pounds and borrowed 250,000 pounds at an average cost of $75.87 per pound to meet 2024 delivery requirements and to establish a sufficient base inventory position for 2025. We delivered 300,000 of the 550,000 non-produced pounds into a term contract in 2024, leaving 250,000 non-produced pounds in ending inventory available for 2025 delivery requirements, if needed, or to be sold into the spot market if it is advantageous to do so.
U3O8 Product Profit and Loss
The following table provides information on our U3O8 product profit and loss.
Unit
U3O8 Product Profit (Loss) by Product Type
U3O8 Product Sales
Produced
$000
13,670
16,646
Non-produced
$000
3,658
16,500
$000
17,328
33,146
U3O8 Product Cost
Produced
$000
6,261
13,914
Non-produced
$000
2,415
22,760
$000
8,676
36,674
U3O8 Product Profit (Loss)
Produced
$000
7,409
2,732
Non-produced
$000
1,243
(6,260)
$000
8,652
(3,528)
U3O8 Pounds Sold
Produced
lb
223,259
270,000
Non-produced
lb
56,741
300,000
lb
280,000
570,000
U3O8 Price per Pound Sold
Produced
$/lb
61.23
61.65
Non-produced
$/lb
64.47
55.00
$/lb
61.89
58.15
U3O8 Cost per Pound Sold
Produced
$/lb
28.04
51.53
Non-produced
$/lb
42.56
75.87
$/lb
30.99
64.34
U3O8 Profit (Loss) per Pound Sold
Produced
$/lb
33.19
10.12
Non-produced
$/lb
21.91
(20.87)
$/lb
30.90
(6.19)
U3O8 Profit (Loss) Margin per Pound Sold
Produced
54.2%
16.4%
Non-produced
34.0%
(37.9)%
49.9%
(10.6)%
In 2023, the average price per pound sold was $61.89 and the average cost per pound sold was $30.99, which resulted in an average profit per pound sold of $30.90 and an average profit margin of nearly 50%. As noted above, the average price and cost per pound sold were better than those received and paid in 2024 due to the higher priced DOE sale and lower cost pre-ramp up inventory sold in 2023.
In 2024, the average price per pound sold was $58.15 and the average cost per pound sold was $64.34, which resulted in an average loss per pound sold of $6.19 and an average loss margin of about 11%. The loss was driven by the sale of non-produced pounds, which were
purchased and borrowed at an average cost of $75.87 per pound. The non-produced pounds were delivered into a sales contract that was executed in 2022 when the long-term price was between $43 and $52 per pound.
U3O8 Production and Ending Inventory
The following table provides information on our production and ending inventory of U3O8 pounds.
Unit
U3O8 Production
Pounds captured
lb
103,487
265,746
Pounds drummed
lb
22,278
249,209
Pounds shipped
lb
-
239,849
Non-produced pounds purchased or borrowed
lb
-
550,000
U3O8 Ending Inventory
Pounds
In-process inventory
lb
82,033
39,169
Plant inventory
lb
22,278
33,919
Conversion inventory - produced
lb
43,790
12,239
Conversion inventory - non-produced
lb
-
250,000
lb
148,101
335,327
Value
In-process inventory
$000
-
Plant inventory
$000
1,343
1,840
Conversion inventory - produced
$000
1,228
Conversion inventory - non-produced
$000
-
18,158
$000
2,571
20,744
Cost per Pound
In-process inventory
$/lb
-
1.07
Plant inventory
$/lb
60.28
54.25
Conversion inventory:
Ad valorem and severance tax
$/lb
0.59
1.57
Cash cost
$/lb
18.60
46.83
Non-cash cost
$/lb
8.85
9.12
Conversion inventory - produced
$/lb
28.04
57.52
Conversion inventory - non-produced
$/lb
-
72.63
$/lb
28.04
71.93
Wellfield production at Lost Creek resumed in 2023 Q2 and 103,487 pounds were captured during the year. Pounds captured increased to 265,746 pounds in 2024 as mining activities accelerated.
Plant production at Lost Creek resumed in 2023 Q3 and 22,278 pounds U3O8 were drummed during the year. Pounds drummed increased to 249,209 pounds in 2024 as plant activities ramped up.
There were no shipments in 2023. The first shipment was completed on February 27, 2024 when 35,445 pounds were delivered to the conversion facility. Pounds shipped increased to 239,849 pounds in 2024.
While pounds captured, drummed, and shipped each increased in 2024 as compared to 2023, the increase was below our initial guidance. The ability to secure drill rigs needed to develop our wellfields and recruit a sustainable workforce proved more time consuming than anticipated. Low dryer production also limited our ability to capture pounds within the plant due to uranium storage limitations within the plant.
We currently have 21 drill rigs turning at Lost Creek, which is sufficient to meet our present development requirements and planned 2025 exploration efforts. The Casper construction shop is functioning well and is capable of meeting our current header house development needs. At present, we are essentially fully staffed at Lost Creek. Significant repairs on Dryer #1 were completed in 2024 Q4 allowing us take Dryer #2 down in Q1 2025 for maintenance, which we anticipate will be complete in coming weeks.
We ended the year with 39,169 in-process pounds, 33,919 drummed pounds, and 262,239 pounds at the conversion facility, including 250,000 purchased pounds.
Because production rates were low during the initial ramp up period, the cost per pound to produce inventory exceeded its NRV. The NRV adjustments to produced inventory decreased from $10.7 million in 2023 to $3.5 million in 2024. Total NRV adjustments in 2024, including $2.5 million of non-produced inventory NRV adjustments, were $6.0 million.
Quarterly U3O8 Product Profit and Loss, and Production, and Ending Inventory
The following two tables provide information on our quarterly U3O8 product profit and loss, production, and ending inventory.
Unit
2024 Q1
2024 Q2
2024 Q3
2024 Q4
U3O8 Product Profit (Loss) by Product Type
U3O8 Product Sales
Produced
$000
-
4,624
6,165
5,857
16,646
Non-produced
$000
-
-
-
16,500
16,500
$000
-
4,624
6,165
22,357
33,146
U3O8 Product Cost
Produced
$000
-
3,127
4,891
5,896
13,914
Non-produced
$000
-
-
-
22,760
22,760
$000
-
3,127
4,891
28,656
36,674
U3O8 Product Profit (Loss)
Produced
$000
-
1,497
1,274
(39)
2,732
Non-produced
$000
-
-
-
(6,260)
(6,260)
$000
-
1,497
1,274
(6,299)
(3,528)
U3O8 Pounds Sold
Produced
lb
-
75,000
100,000
95,000
270,000
Non-produced
lb
-
-
-
300,000
300,000
lb
-
75,000
100,000
395,000
570,000
U3O8 Price per Pound Sold
Produced
$/lb
-
61.65
61.65
61.65
61.65
Non-produced
$/lb
-
-
-
55.00
55.00
$/lb
-
61.65
61.65
56.60
58.15
U3O8 Cost per Pound Sold
Produced
$/lb
-
41.69
48.91
62.06
51.53
Non-produced
$/lb
-
-
-
75.87
75.87
$/lb
-
41.69
48.91
72.55
64.34
U3O8 Profit (Loss) per Pound Sold
Produced
$/lb
-
19.96
12.74
(0.41)
10.12
Non-produced
$/lb
-
-
-
(20.87)
(20.87)
$/lb
-
19.96
12.74
(15.95)
(6.19)
U3O8 Profit (Loss) Margin per Pound Sold
Produced
0.0%
32.4%
20.7%
(0.7)%
16.4%
Non-produced
0.0%
0.0%
0.0%
(37.9)%
(37.9)%
0.0%
32.4%
20.7%
(28.2)%
(10.6)%
Unit
2024 Q1
2024 Q2
2024 Q3
2024 Q4
U3O8 Production
Pounds captured
lb
38,221
70,679
75,075
81,771
265,746
Pounds drummed
lb
39,229
64,170
71,804
74,006
249,209
Pounds shipped
lb
35,445
70,390
67,488
66,526
239,849
Non-produced pounds purchased or borrowed
lb
-
-
-
550,000
550,000
U3O8 Ending Inventory
Pounds
In-process inventory
lb
80,465
86,204
90,140
39,169
Plant inventory
lb
26,062
21,570
26,580
33,919
Conversion inventory - produced
lb
79,235
74,625
40,713
12,239
Conversion inventory - non-produced
lb
-
-
-
250,000
lb
185,762
182,399
157,433
335,327
Value
In-process inventory
$000
-
Plant inventory
$000
1,593
1,072
1,499
1,840
Conversion inventory - produced
$000
3,105
3,555
2,320
Conversion inventory - non-produced
$000
-
-
-
18,158
$000
4,698
5,074
4,246
20,744
Cost per Pound
In-process inventory
$/lb
-
5.19
4.74
1.07
Plant inventory
$/lb
61.12
49.70
56.40
54.25
Conversion inventory:
Ad valorem and severance tax
$/lb
0.53
0.67
1.63
1.57
Cash cost
$/lb
28.47
36.77
45.26
46.83
Non-cash cost
$/lb
10.19
10.20
10.09
9.12
Conversion inventory - produced
$/lb
39.19
47.64
56.98
57.52
Conversion inventory - non-produced
$/lb
-
-
-
72.63
$/lb
39.19
47.64
56.98
71.93
During the year, production increased each quarter ultimately reaching 81,771 pounds captured in 2024 Q4. Similarly, pounds drummed also increased quarter on quarter. During 2024 Q4, we purchased 300,000 pounds and borrowed 250,000 pounds at an average cost of $75.87 per pound to meet 2024 delivery requirements and to establish a sufficient base inventory position for 2025. We delivered 300,000 of the 550,000 non-produced pounds into term contracts in 2024, leaving 250,000 non-produced pounds in ending inventory available for 2025 delivery requirements, if needed.
As discussed above, we continued to ramp up operations in 2024, which generally resulted in increases to our cost per pound amounts during the year, prior to NRV adjustments.
Year Ended December 31, 2024, Compared to Year Ended December 31, 2023
The following table summarizes the results of operations for the years ended December 31, 2024, and 2023:
(expressed in thousands of U.S. dollars, except per share and non-GAAP per pound data)
Year Ended December 31,
Change
Sales
33,706
17,679
16,027
Cost of sales
(42,679)
(19,365)
(23,314)
Gross loss
(8,973)
(1,686)
(7,287)
Operating costs
(54,116)
(29,156)
(24,960)
Operating loss
(63,089)
(30,842)
(32,247)
Net interest income
3,341
1,471
1,870
Mark to market gain (loss)
6,444
(1,586)
8,030
Foreign exchange gain
(245)
Other income (loss)
(24)
Net loss
(53,189)
(30,656)
(22,533)
Foreign currency translation adjustment
(547)
1,018
Comprehensive loss
(52,718)
(31,203)
(21,515)
Loss per common share:
Basic
(0.17)
(0.12)
(0.05)
Diluted
(0.17)
(0.12)
(0.05)
U3O8 pounds sold
570,000
280,000
290,000
U3O8 price per pound sold
58.15
61.89
(3.74)
U3O8 cost per pound sold
64.34
30.99
33.35
U3O8 profit (loss) per pound sold
(6.19)
30.90
(37.09)
Sales
Sales per the financial statements includes U3O8 sales and disposal fees. Due to the nature of our contracts, we have a limited number of deliveries, which do not occur consistently during the year. Sales revenues are recognized when the product is transferred to the purchaser.
During 2024, we delivered 570,000 pounds under contracts that were negotiated in prior years at an average price of $58.15 for revenues of $33.1 million. During 2023 we made our first deliveries since 2020. During that year we delivered 280,000 pounds at an average price of $61.89 for revenues of $17.3 million. We also realized revenues from disposal fees of $0.6 million and $0.4 million in 2024 and 2023, respectively, as our customers increased their reclamation activities.
Cost of Sales
Cost of sales per the financial statements includes U3O8 costs of sales and lower of cost or NRV adjustments and consists of the following:
(expressed in thousands of U.S. dollars)
Year Ended December 31,
Cost of Sales
Change
U3O8 product cost
36,674
8,676
27,998
Lower of cost or NRV adjustments
6,005
10,689
(4,684)
42,679
19,365
23,314
Cost of sales was $42.7 million and $19.4 million for the years ended December 31, 2024, and 2023, respectively. Excluding NRV adjustments, U3O8 product costs were $36.7 million and $8.7 million for the years ended December 31, 2024, and 2023, respectively. In 2024, we sold 270,000 produced pounds with a cost per pound sold of $51.53 and 300,000 non-produced pounds at a cost per pound sold of $75.87, which resulted in total U3O8 product costs of $36.7 million or $64.34 per pound. All sales in 2023 were from pre-existing conversion facility inventories that the Company had in place at the end of 2022. In 2023, we sold 223,259 produced pounds with a cost per pound sold of $28.04 and 56,741 non-produced pounds at a cost per pound sold of $42.56, which resulted in total U3O8 product costs of $8.7 million or $30.99 per pound.
Cost of sales in 2024 and 2023 included $6.0 million and $10.7 million of NRV adjustments, respectively. Because of low production rates, inventory valuations, which include production costs, exceeded the produced inventory’s NRV. As a result, produced inventory values were reduced to the inventory’s NRV, effectively expensing $3.5 million and $10.7 million of production costs to cost of sales in 2024 and 2023, respectively. The $7.2 million decrease in produced inventory NRV adjustments from 2023 to 2024 was attributable to increased production for the respective periods. As plant production increases in 2025, we expect the produced inventory NRV adjustments to continue to decrease and ultimately stop. In addition, we purchased 300,000 pounds of U3O8 in 2024, of which 50,000 pounds were sold in 2024 Q4. Because of decreases in uranium prices, we recognized $2.5 million in non-produced inventory valuation adjustments, which are included in the 2024 $6.0 million total NRV adjustments.
Gross Loss
Gross loss is based on sales, which includes disposal fees, and cost of sales, which includes NRV adjustments. Including NRV adjustments, the gross loss was $9.0 million and $1.7 million for the years ended December 31, 2024, and 2023, respectively. Because of low production in 2024, the Company purchased 300,000 pounds with cash at spot uranium prices and borrowed 250,000 pounds that were valued at spot uranium prices. The non-produced pounds were used to meet a 300,000-pound delivery requirement in 2024 Q4, which resulted in an average U3O8 loss of approximately $20.87 per pound sold and contributed to the larger gross loss in 2024.
Operating Costs
The following table summarizes the operating costs for the years ended December 31, 2024, and 2023:
(expressed in thousands of U.S. dollars)
Year Ended December 31,
Operating Costs
Change
Exploration and evaluation
3,803
2,109
1,694
Development
41,509
20,396
21,113
General and administration
8,044
6,154
1,890
Accretion
54,116
29,156
24,960
Total operating costs increased $25.0 million in 2024. The increase was primarily due to development costs, which increased $21.1 million due to ramp up activities at Lost Creek and initial pre-mining development activity at Shirley Basin.
Exploration and evaluation expense consists of labor and the associated costs of the exploration, evaluation, and regulatory departments, as well as land holding and exploration costs on properties that have not reached the development or operations stage. The $1.7 million increase in 2024 was primarily due to additional staffing and outside service costs.
The Company is considered an exploration stage issuer and expenses its pre-production development costs. As noted above, these development costs are incurred in advance of production from the related mining areas. Development expense includes costs incurred at the Lost Creek Project not directly attributable to current production activities, including wellfield construction, drilling, and development costs. It also includes costs incurred at the Shirley Basin Project not directly attributable to the construction of the capitalizable assets of the project, including the installation of the wellfield monitor well ring and other development costs. The following table summarizes the development costs included in operating costs for the years ended December 31, 2024 and 2023:
(expressed in thousands of U.S. dollars)
Year Ended December 31,
Development Costs
Change
Lost Creek mine unit development
33,975
15,335
18,640
Lost Creek disposal well development
4,173
4,362
(189)
Shirley Basin mine development
3,274
2,714
Other development
(52)
41,509
20,396
21,113
Development expenses increased approximately $21.1 million in the year ended December 31, 2024. The increases were driven by increased drilling activities and the related wellfield construction costs that relate to the Lost Creek mine unit (“MU”) two development program. Lost Creek disposal well development costs in 2023 and 2024 totaled $8.5 million, of which $7.7 million related to the construction of a new disposal well at Lost Creek. At Shirley Basin, we incurred approximately $3.3 million in development costs in 2024. Development activities at Shirley Basin included drilling costs related to the installation of the first monitor well ring.
General and administration expenses relate to the administration, finance, investor relations, land, and legal functions, and consist principally of personnel, facility, and support costs. The $1.9 million increase in 2024 was primarily related to higher labor costs, stock based compensation costs, and professional fees.
Other Income and Expenses
Net interest income increased from $1.5 million in 2023 to $3.3 million in 2024, reflecting higher interest income received on our cash and cash equivalent accounts and lower interest expense following the payoff of the Company’s state bond loan in April 2024. The higher interest income was driven by a combination of higher interest rates and higher cash balances.
Mark-to-market adjustments include revaluations of the Company’s warrant liability and uranium inventory loan. As a part of the February 2021 and February 2023 underwritten public offerings, we issued warrants that were priced in U.S. dollars. For the year ended December 31, 2024, the warrant liability decreased significantly due to the exercise of 2021 warrants and changes in the factors used in the Black-Scholes calculations of the warrant liability, including decreases in the Company’s stock price and changes in exchange rates. The 2024 warrant liability revaluation resulted in a gain of $5.3 million as compared to a loss of $1.6 million in 2023. During 2024, the Company entered into a uranium inventory loan agreement and borrowed 250,000 pounds. The loan valuation, which is based on average spot uranium prices, decreased $1.1 million in 2024, resulting in a gain.
Earnings (loss) per Common Share
The basic and diluted loss per common share was $0.17 and $0.12 for the years ended December 31, 2024, and 2023, respectively. The diluted loss per common share is equal to the basic loss per common share due to the anti-dilutive effect of all convertible securities in periods of loss.
Liquidity and Capital Resources
As shown in the Consolidated Statements of Cash Flow, our cash and cash equivalents, and restricted cash and cash equivalents, increased from the December 31, 2023 balance of $68.2 million to $87.1 million as of December 31, 2024. During 2024, we generated $99.9 million from financing activities, and used $71.9 million for operating activities and $9.0 million for investing activities.
Operating activities used $71.9 million in 2024. We sold 570,000 pounds of U3O8 for $33.1 million, however $16.5 million was in trade receivables at year end and was subsequently collected in January 2025. We collected $0.6 million of disposal fees and received $3.7 million of interest income. We had $0.3 million in interest expense and spent $14.5 million on production costs, $24.2 million on uranium purchase costs, and $48.5 million on operating costs, and we posted a $3.8 million deposit related to the uranium inventory loan. We had a $1.5 million unfavorable working capital movement primarily related to increases in leases receivable.
Investing activities used $9.0 million of cash in 2024. We spent $3.6 million on operating equipment at Lost Creek, and $5.4 million on construction and other equipment at Shirley Basin.
Financing activities provided $99.9 million in the year ended December 31, 2024. In July, we closed an equity financing by issuing 65,722,500 shares, including 8,572,500 overallotment shares, at $1.05 per share for net proceeds of $65.2 million. We received net proceeds of $27.8 million from the sale of common shares through our At Market Facility, and $12.4 million from the exercise of warrants and stock options. We spent $5.7 million on the Wyoming bond loan, ultimately paying off the loan in March 2024, and paid $0.1 million in settlement of RSUs redeemed for cash.
Wyoming State Bond Loan
On October 23, 2013, we closed a $34.0 million Sweetwater County, State of Wyoming, Taxable Industrial Development Revenue Bond financing program loan (“State Bond Loan”). The State Bond Loan called for payments of interest at a fixed rate of 5.75% per annum on a quarterly basis, which commenced January 1, 2014. The principal was to be payable in 28 quarterly installments, which commenced January 1, 2015. The State Bond Loan was secured by all the assets of the Lost Creek Project.
On October 1, 2019, the Sweetwater County Commissioners and the State of Wyoming approved an eighteen-month deferral of principal payments beginning October 1, 2019. On October 6, 2020, the State Bond Loan was again modified to defer principal payments for an additional eighteen months. Quarterly principal payments were resumed on October 1, 2022, with the last payment due on October 1, 2024.
On February 29, 2024, we provided notice to Sweetwater County, the State Treasurer and the Trustee of our intention to prepay all remaining amounts on the State Bond Loan on April 1, 2024. The payment was made March 27, 2024, after which the loan was paid in full.
Universal Shelf Registration and At Market Facility
On May 29, 2020, we entered into an At Market Issuance Sales Agreement (the “Sales Agreement”) with B. Riley Securities, Inc. (“B. Riley Securities”), relating to our common shares. On June 7, 2021, we amended and restated the Sales Agreement to include Cantor Fitzgerald & Co. (“Cantor,” and together with B. Riley Securities, the “Agents”) as a co-agent. Under the Sales Agreement, as amended, we may, from time to time, issue and sell common shares at market prices on the NYSE American or other U.S. market through the agents for aggregate sales proceeds of up to $50 million. The Sales Agreement was originally filed in conjunction with a then-active universal shelf registration statement on Form S-3.
On December 17, 2021, we entered into an amendment to the Sales Agreement with the Agents to, among other things, reflect the registration statement on file at the time. In February 2023, in conjunction with our underwritten public offering, we filed a prospectus supplement by which we decreased the amount of common stock offered pursuant to the Amended Sales Agreement.
On June 28, 2023, we filed a new universal shelf registration statement on Form S-3 with the SEC through which we may offer and sell, from time to time, in one or more offerings, at prices and terms to be determined, up to $175 million of our common shares, warrants to purchase our common shares, our senior and subordinated debt securities, and rights to purchase our common shares and/or senior and subordinated debt securities. The registration statement became effective July 19, 2023, for a three-year period.
On July 19, 2023, we entered into a further amendment to the Amended Sales Agreement (“Amendment No. 2” and hereafter the “Amended Sales Agreement”) with the Agents to, among other things, reflect the new registration statement under which we may sell up to $50 million from time to time through or to the Agents under the Amended Sales Agreement, in addition to amounts previously sold under the Sales Agreement. Subsequently, we filed a new prospectus supplement in June 2024 under which we may sell up to $100 million from time to time through or to the Agents under the Amended Sales Agreement, including the common shares previously sold under the Sales Agreement.
In 2024, we utilized the Amended Sales Agreement for gross proceeds of $28.6 million from sales of 16,939,825 common shares.
2023 Underwritten Public Offering
On February 21, 2023, the Company closed a $46.1 million underwritten public offering of 39,100,000 common shares and accompanying warrants to purchase up to 19,550,000 common shares, at a combined public offering price of $1.18 per common share and accompanying warrant. The gross proceeds to Ur-Energy from this offering were approximately $46.1 million. After fees and expenses of $3.0 million, net proceeds to the Company were approximately $43.1 million. The warrants expire in February 2026.
2024 Underwritten Public Offering
On July 29, 2024, the Company closed an underwritten public offering of 57,150,000 common shares at a price of $1.05 per common share. The Company also granted the underwriters a 30-day option to purchase up to 8,572,500 additional common shares on the same terms. The option was exercised in full. Including the exercised option, the Company issued a total of 65,722,500 common shares. The gross proceeds to the Company from this offering were approximately $69.0 million. After fees and expenses of $3.8 million, net proceeds to the Company were approximately $65.2 million.
Liquidity Outlook
As of April 9, 2025, our unrestricted cash position was $71.8 million.
We have seven multi-year sales contracts in place and realized revenues of $33.1 million from the sale of 570,000 pounds of U3O8 in 2024. We expect to realize revenues of $27.1 million from the sale of 440,000 pounds of uranium in 2025. As of April 9, 2025, we had 368,540 pounds of conversion facility inventory having made three shipments totaling 106,301 pounds to the conversion facility through March 2025. Deliveries into term contracts in 2025 are expected to be made from our existing conversion facility inventory and new production from Lost Creek.
In addition to normal production and operating costs at Lost Creek, we anticipate spending approximately $38.2 million at Shirley Basin on construction, equipment purchases, mine unit development, and initial production costs. We expect that these capital projects will be funded by operating cash flow and cash on hand. We have no immediate plans to issue additional securities or obtain additional funding other than that which may be required due to the uneven nature of cash flows generated from operations.
Looking Ahead
We currently have 21 drill rigs working at Lost Creek, which is sufficient for our present development requirements and our planned exploration programs in 2025, as well as initial deployment of rigs to Shirley Basin. We brought HH 2-12 online in January 2025 and brought HH 2-13 online in March 2025.
At present, we have a full complement of approximately 85 Lost Creek employees. We note that retention has improved in recent months, including within our Lost Creek management group. This has allowed us to better train our staff and place a greater focus on their safety. The Casper shop is functioning well and meeting our present header house development needs for Lost Creek and is in position to meet our development needs at Shirley Basin as we move towards production there.
While we experienced production challenges in 2024, we believe that many of the equipment and process issues are behind us in our ramp-up efforts at Lost Creek. Most recently, we completed significant repairs on Dryer #1 in Q4 2024 which allowed us to take Dryer #2 down in Q1 for maintenance, which is expected to be completed shortly.
By purchasing and borrowing inventory in Q4 2024, we took proactive measures to meet our 2024 delivery requirements and to establish a sufficient base inventory position for 2025. Subsequent to year end, we reached an agreement to defer delivery of 300,000 pounds U3O8 scheduled for sale in 2025; that delivery will now be made in 2026 H1. As a result of this agreement, we plan to deliver 440,000 pounds U3O8 in 2025 for approximately $27.1 million in sales proceeds.
As we continue to advance Lost Creek to steady-state operations, we believe these steps to increase our inventory position and manage our delivery commitments will best position us to timely meet our 2025 sales commitments, satisfy our physical uranium loan obligations, and position us to substantially increase our production capacity in 2026 and beyond with the addition of Shirley Basin, which we anticipate to occur in early 2026.
Our development and pre-construction efforts at Shirley Basin advanced well during 2024, with adept management of change to best incorporate historical infrastructure while obtaining significant cost savings as compared to new construction. The modular office building for the site is being constructed and is expected to be complete in 2025 Q3. Earthwork at the plant site is in progress with compaction expected to be completed in April to allow concrete work to begin in May. In 2025 Q2, we expect to return to wellfield development work and additional roadwork.
Hiring for Shirley Basin has begun with several key management positions already filled and with the training of several construction staff new hires in progress. We expect to benefit through lateral moves of staff from Lost Creek as well as continuing to train Shirley Basin staff with their counterparts at Lost Creek. Our phased hiring program is anticipated to allow for more thorough safety and task training of staff prior to commencement of operations.
We look forward to the commencement of operations at Shirley Basin, as it will diversify our production sources and further support our efforts to remain a leading U.S. uranium producer. We also anticipate restarting exploration programs to identify additional mineral resources and supplement future production.
As discussed, we have secured multi-year sales agreements with leading nuclear companies, including several which include market-related pricing components. We now have seven agreements that call for combined annual delivery of a base amount of 440,000 to 1,300,000 pounds of U3O8 from 2025 through 2030, with additional deliveries of 100,000 called for in 2032 and 2033. Sales prices are anticipated to be profitable on an all-in production cost basis and escalate annually from initial pricing.
Our cash position as of April 9, 2025, was $71.8 million.
As always, we will focus on maintaining safe and compliant operations.
Outstanding Share Data
As of December 31, 2024, and 2023, the Company’s capital consisted of the following:
Share Data
December 31, 2024
December 31, 2023
Common shares
364,101,038
270,898,900
Shares issuable upon the exercise or redemption of:
Stock options
8,594,492
8,900,335
Restricted share units
1,069,645
641,910
Warrants
19,520,500
27,708,750
393,285,675
308,149,895
Off Balance Sheet Arrangements
We have not entered any material off balance sheet arrangements such as guaranteed contracts, contingent interests in assets transferred to unconsolidated entities, derivative instrument obligations, or with respect to any obligations under a variable interest entity arrangement.
Financial Instruments and Other Instruments
As of December 31, 2024, and 2023, the Company’s cash and cash equivalents, and restricted cash and cash equivalents are composed of:
(expressed in thousands of U.S. dollars)
Cash and cash equivalents, and restricted cash and cash equivalents
December 31, 2024
December 31, 2023
Cash and cash equivalents
76,055
59,700
Restricted cash and cash equivalents
11,023
8,549
87,078
68,249
Credit risk
Financial instruments that potentially subject the Company to concentrations of credit risk consist of cash and cash equivalents, and restricted cash and cash equivalents. These assets include Canadian dollar and U.S. dollar denominated certificates of deposit, money market accounts, and demand deposits. These instruments are maintained at financial institutions in Canada and the U.S. Of the amount held on deposit, approximately $0.6 million is covered by the Canada Deposit Insurance Corporation, the Securities Investor Protection Corporation, or the U.S. Federal Deposit Insurance Corporation, leaving approximately $86.4 million at risk on December 31, 2024, should the financial institutions with which these amounts are invested be rendered insolvent. The Company does not consider any of its financial assets to be impaired as of December 31, 2024.
Currency risk
As of December 31, 2024, we maintained a balance of approximately $2.7 million Canadian dollars. The funds will be used to pay Canadian dollar expenses and are considered to be a low currency risk to the Company.
Liquidity risk
Liquidity risk is the risk that the Company will not be able to meet its financial obligations as they come due. As of December 31, 2024, the Company’s current financial liabilities consisted of accounts payable and accrued liabilities of $4.5 million, the current portion of leases payable of $0.3 million and the repayment of the inventory loan currently valued at $18.2 million. As of December 31, 2024, we had $76.1 million of cash and cash equivalents, $16.5 million in accounts receivable and $20.7 million in inventory.
Interest rate risk
The Company has completed a sensitivity analysis to estimate the impact that a change in interest rates would have on the net loss and considers the change to be a low interest rate risk to the Company.

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ITEM 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
Item 7A. Quantitative AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
Market risk
Market risk is the risk to the Company of adverse financial impact due to changes in the fair value or future cash flows of financial instruments because of fluctuations in interest rates and foreign currency exchange rates.
Commodity Price Risk
The Company is subject to market risk related to the market price of uranium. Future sales would be impacted by both spot and long-term uranium price fluctuations. Historically, uranium prices have been subject to fluctuation, and the price of uranium has been and will continue to be affected by numerous factors beyond our control, including the demand for nuclear power, political and economic conditions, governmental legislation in uranium producing and consuming countries, and production levels and costs of production of other producing companies. The average spot market price was $64.80 per pound as of April 9, 2025.
Transactions with Related Parties
During the fiscal year ended December 31, 2024, we did not participate in any reportable transactions with related parties.
Proposed Transactions
As is typical of the mineral exploration, development, and mining industry, we will consider and review potential merger, acquisition, investment and venture transactions and opportunities that could enhance shareholder value. Timely disclosure of such transactions is made as soon as reportable events arise.
New Accounting Pronouncements Which were Implemented this Year
In November 2023, the Financial Accounting Standards Board issued Accounting Standards Update (“ASU”) 2023-07, Segment Reporting (Topic 280): Improvements to Reportable Segment Disclosures. This ASU requires annual and interim disclosures about significant segment expenses that are regularly provided to the chief operating decision maker and included within each reported measure of segment profit or loss as well as the amount and composition of other segment items. All disclosure requirements under this ASU are also required for public entities with a single reportable segment. This ASU is effective for the Company’s Annual Report on Form 10-K for the year ended December 31, 2024, and subsequent interim periods, with early adoption permitted.
Critical Accounting Estimates
Our significant accounting policies are described in note 2 of Notes to Consolidated Financial Statements. As described in note 2, we are required to make estimates and assumptions that affect the reported amounts and related disclosures of assets, liabilities, revenue, and expenses. Our estimates are based on our experience and our interpretation of economic, political, regulatory, and other factors that affect our business prospects. Actual results may differ significantly from certain critical accounting estimates as discussed below.
Inventory
We allocate the production costs of the Lost Creek facility to estimated inventory quantities at various stages of production to determine inventory valuation. We estimate the net realizable value of the inventory based on estimated prices and revenues from the sale of the inventory. Our inventories are then valued at the lower of the estimated cost or net realizable value. Changes in these estimates may materially impact the value of the inventory.
Impairment testing
Long-lived assets are reviewed for impairment whenever events or changes in circumstances indicate the carrying amount of an asset may not be recoverable. Management applies significant judgment to assess mineral properties and capital assets for impairment indicators that could give rise to the requirement to conduct a formal impairment test. Circumstances that could trigger a review include, but are not limited to: significant decreases in the market price of the asset; significant adverse changes in the business climate or legal factors; significant changes in expected capital, operating, or reclamation costs; current period cash flow or operating losses combined with a history of losses or a forecast of continuing losses associated with the use of the asset; and current expectation that the asset will more likely than not be sold or disposed of significantly before the end of its estimated useful life.
When potential impairment is indicated, management calculates the estimated undiscounted future net cash flows relating to the asset or asset group using estimated future prices, recoverable resources and operating, capital, and reclamation costs. When the carrying value of an asset exceeds the related undiscounted cash flows, the asset is written down to its estimated fair value, which is determined using discounted future net cash flows, or other measures of fair value. Changes in these estimates may materially impact the carrying value of the assets. Management did not identify impairment indicators that would require a formal impairment test.
Lost Creek has been the Company’s sole source of uranium concentrates produced and sold to generate sales revenues since 2013. The economic viability of the Company’s mining activities, including the expected duration and profitability of Lost Creek and of any future ISR mines, such as Shirley Basin, has many risks and uncertainties. These include, but are not limited to: (i) a significant, prolonged decrease in the market price of uranium; (ii) difficulty in marketing and/or selling uranium concentrates; (iii) significantly higher than expected capital costs to construct the mine and/or processing plant; (iv) significantly higher than expected extraction costs; (v)
significantly lower than expected uranium extraction; (vi) significant delays, reductions or stoppages of uranium extraction activities; and (vii) the introduction of significantly more stringent regulatory laws and regulations.
Our mining activities may change because of any one or more of these risks and uncertainties and there is no assurance that any mineral deposit from which we extract uranium or other minerals will result in profitable mining activities.
Asset Retirement Obligations
For mining properties, various federal and state mining laws and regulations require the Company to reclaim the surface areas and restore groundwater quality to the pre-existing quality or a concentration that supports a class of use after the completion of mining. The Company records the fair value of an asset retirement obligation as a liability in the period in which it incurs an obligation associated with the retirement of tangible long-lived assets that result from the acquisition, construction, development and/or normal use of the assets.
Asset retirement obligations consist of estimated final well abandonments, plant closure and removal and associated reclamation and restoration costs to be incurred by the Company in the future. The estimated fair value of the asset retirement obligation is based on the current cost escalated at an inflation rate and discounted at a credit adjusted risk-free rate. This liability is capitalized as part of the cost of the related asset and amortized over its remaining productive life. The liability is accreted until it reaches the estimated future reclamation cost and remains until the Company settles the obligation. Changes in these estimates may materially impact the value of the obligations.

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ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA
Item 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA
The financial statements required by this Item 8 are set forth in Item 15.
Our Consolidated Financial Statements appear beginning at Page. The Report of Independent Registered Public Accounting Firm (PCAOB ID 243) appears beginning on Page. The Report of Independent Registered Public Accounting Firm (PCAOB ID 271) appears beginning on Page.

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ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS
Item 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND FINANCIAL DISCLOSURE
None.

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ITEM 9A. CONTROLS AND PROCEDURES
Item 9A. CONTROLS AND PROCEDURES
(a)Evaluation of Disclosure Controls and Procedures
As of the fiscal year ended December 31, 2024, under the supervision of the Chief Executive Officer and the Chief Financial Officer, the Company evaluated the effectiveness of its disclosure controls and procedures, as such term is defined in Rule 13a-15(e) and Rule 15d-15(e) under the Securities Exchange Act of 1934 (the “Exchange Act”). Based on this evaluation, the Chief Executive Officer and the Chief Financial Officer have concluded that the Company’s disclosure controls and procedures are effective to ensure that information the Company is required to disclose in reports that are filed or submitted under the Exchange Act: (1) is recorded, processed and summarized effectively and reported within the time periods specified in SEC rules and forms, and (2) is accumulated and communicated to Company management, including the Chief Executive Officer and the Chief Financial Officer, as appropriate to allow timely decisions regarding required disclosure. The Company’s disclosure controls and procedures include components of internal control over financial reporting. No matter how well designed and operated, internal controls over financial reporting can provide only reasonable, but not absolute, assurance that the control system’s objectives will be met.
(b)Management’s Report on Internal Control over Financial Reporting
Pursuant to Section 404 of the Sarbanes-Oxley Act of 2002, the Company’s management is responsible for establishing and maintaining adequate internal control over financial reporting, as such term is defined in Exchange Act Rules 13a-15(f) and 15d-15(f). The
Company’s internal control over financial reporting is a process designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with US GAAP.
All internal control systems, no matter how well designed, have inherent limitations. Therefore, even those systems determined to be effective can provide only reasonable assurance with respect to financial statement preparation and presentation. Because of the inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Projections of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.
As of December 31, 2024, management assessed the effectiveness of the Company’s internal control over financial reporting based on the criteria established in Internal Control-Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO). Based on its assessment using those criteria, management concluded that the Company maintained effective internal control over financial reporting as of December 31, 2024.
(c)Attestation Report of Registered Public Accounting Firm
This annual report does not include an attestation report of the Company’s registered public accounting firm regarding internal controls over financial reporting. Management’s report was not subject to attestation by our registered public accounting firm pursuant to law, rules and regulations that permit us to provide only management’s report in this annual report.
(d)Changes in Internal Controls over Financial Reporting
No changes in our internal control over financial reporting occurred during the quarter ended December 31, 2024 that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

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ITEM 9B. OTHER INFORMATION
Item 9B. OTHER INFORMATION
During the quarter ended December 31, 2024, none of our directors or officers (as defined in Rule 16a-1(f) of the Exchange Act) adopted or terminated a “Rule 10b5-1 trading arrangement” or “non-Rule 10b5-1 trading arrangement,” as each term is defined in Item 408 of Regulation S-K.

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ITEM 10. DIRECTORS, EXECUTIVE OFFICERS AND CORPORATE GOVERNANCE
Item 10. DIRECTORS, EXECUTIVE OFFICERS AND CORPORATE GOVERNANCE
Information relating to this item will be included in an amendment to this report or in the proxy statement for our 2025 Annual Meeting of Shareholders and is incorporated by reference in this report.
Code of Ethics
We have adopted a Code of Ethics (“Code”) which applies to all employees, officers, and directors. The full text of the Code is available on our website at https://www.ur-energy.com/investors/corporate-governance/governance-documents/. We will post any amendments to, or waivers from, the Code on our corporate website or by filing a Current Report on Form 8-K.

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ITEM 11. EXECUTIVE COMPENSATION
Item 11. EXECUTIVE COMPENSATION
Information relating to this item will be included in an amendment to this report or in the proxy statement for our 2025 Annual Meeting of Shareholders and is incorporated by reference in this report.

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ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS
Item 12. SECURITY OWNERSHIP OF Certain BENEFICIAL OWNERS AND MANAGEMENT AND RELATED STOCKHOLDER MATTERS
Information relating to this item will be included in an amendment to this report or in the proxy statement for our 2025 Annual Meeting of Shareholders and is incorporated by reference in this report.

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ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS
Item 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS, AND DIRECTOR INDEPENDENCE
Information relating to this item will be included in an amendment to this report or in the proxy statement for our 2025 Annual Meeting of Shareholders and is incorporated by reference in this report.

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ITEM 14. PRINCIPAL ACCOUNTING FEES AND SERVICES
Item 14. PRINCIPAL ACCOUNTANT FEES AND SERVICES
Information relating to this item will be included in an amendment to this report or in the proxy statement for our 2025 Annual Meeting of Shareholders and is incorporated by reference in this report.
PART IV

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ITEM 15. EXHIBITS, FINANCIAL STATEMENT SCHEDULES
Item 15. EXHIBITS AND FINANCIAL STATEMENT SCHEDULES
Financial Statements and Financial Statement Schedules
The Consolidated Financial Statements filed as part of this Form 10-K begin on page.
Incorporated by Reference
Exhibit Number
Exhibit Description
Form
Filing Date of
Report
Exhibit
Filed
Herewith
3.1
Articles of Continuance and Articles of Amendment
S-3
1/10/2014
3.1
3.2
Amended By-Law No. 1
S-3
1/10/2014
3.2
3.3
By-Law No. 2 (Advance Notice)
8-K
2/25/2016
3.1
4.1
Description of Registrant Securities
10-K
3/06/2023
4.2
4.2
Warrant Agreement, dated February 21, 2023, between the Company, Computershare Inc and Computershare Trust Company, N.A.
8-K
2/21/2023
4.1
10.1
Amended and Restated At Market Issuance Sales Agreement, dated as of June 7, 2021, between the Company, B. Riley Securities, Inc. and Cantor Fitzgerald & Co.
8-K
6/9/2021
1.1
10.1.1
Amendment No. 1 to the Amended and Restated At Market Issuance Sales Agreement, dated December 17, 2021, between the Company, B. Riley Securities, Inc. and Cantor Fitzgerald & Co.
8-K
12/21/2021
1.2
10.1.2
Amendment No. 2 to the Amended and Restated At Market Issuance Sales Agreement, dated July 19, 2023 between the Company, B. Riley Securities, Inc. and Cantor Fitzgerald & Co.
8-K
7/20/2023
3.1
10.2
Employment Agreement with Roger L. Smith, effective as of May 1, 2008, as amended on May 16, 2011, October 24, 2011 and January 1, 2013(*)
10-K
3/3/2014
10.9
10.2.1
Amendment 2020-01 to Employment Agreement with Roger L. Smith, dated as of December 10, 2020(*)
10-K
2/26/2021
10.17
10.3
Employment Agreement with Steven M. Hatten, effective as of May 17, 2011 as amended on October 24, 2011 and January 1, 2013(*)
10-K
3/3/2014
10.10
10.3.1
Amendment 2020-01 to Employment Agreement with Steven M. Hatten, dated December 10, 2020(*)
10-K
2/26/2021
10.18
10.3.2
Amendment 2023-01 to Employment Agreement with Steven M. Hatten, dated April 7, 2023(*)
10-Q
5/1/2023
10.2
10.4
Employment Agreement with John W. Cash, effective as of May 17, 2011, as amended on October 24, 2011 and January 1, 2013(*)
10-K
3/3/2014
10.11
10.4.1
Amendment 2020-01 to Employment Agreement with John W. Cash, dated December 10, 2020(*)
10-K
2/26/2021
10.19
10.4.2
Amendment 2023-01 to Employment Agreement with John W. Cash, dated April 7, 2023(*)
10-Q
5/1/2023
10.1
10.5
Employment Agreement with Penne A. Goplerud, effective as of May 17, 2011, as amended on October 24, 2011 and January 1, 2013(*)
10-K
3/3/2014
10.12
10.5.1
Amendment 2020-01 to Employment Agreement with Penne A. Goplerud, dated December 10, 2020
10-K
2/26/2021
10.20
10.6
Employment Agreement between Ur-Energy USA Inc. and Ryan S. Schierman, dated March 28, 2024(*)
8-K
3/28/2024
10.1
10.7
Ur-Energy Inc. Amended and Restated Stock Option Plan 2005
8-K
4/17/2017
10.1
10.8
Ur-Energy Inc. Amended and Restated Restricted Share Unit & Equity Incentive Plan
8-K
4/16/2021
10.1
16.1
Letter of PricewaterhouseCoopers LLP, dated October 2, 2024
8-K
10/2/2024
16.1
19.1
Ur-Energy Inc. Policies Concerning Confidentiality, Public Disclosure and Restrictions on Trading of Securities
X
21.1
Subsidiaries of the Registrant
10-K
3/06/2023
21.1
23.1
Consent of BDO USA, P.C.
X
23.2
Consent of PricewaterhouseCoopers LLP
X
23.3
Consent of WWC Engineering with regard to the Technical Report Summary on the Lost Creek ISR Uranium Property, Sweetwater County, Wyoming, USA and the Technical Report Summary on Shirley Basin Project, Carbon County, Wyoming, USA
X
31.1
Certification of CEO Pursuant to Exchange Act Rules 13a-14 and 15d-14, as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002
X
31.2
Certification of CFO Pursuant to Exchange Act Rules 13a-14 and 15d-14, as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002
X
32.1
Certification of CEO Pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002
X
32.2
Certification of CFO Pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002
X
96.1
Technical Report Summary on the Lost Creek ISR Uranium Property, Sweetwater County, Wyoming, USA
10-K
3/6/2024
96.1
96.2
Technical Report Summary on the Shirley Basin ISR Uranium Property, Carbon County, Wyoming, USA, as amended
10-K/A
3/11/2024
96.2
97.1
Ur-Energy Inc. Executive Compensation Clawback Policy
10-K
3/6/2024
99.1
Location maps (1)
X
101.INS
XBRL Instance Document
101.SCH
XBRL Schema Document
101.CAL
XBRL Calculation Linkbase Document
101.DEF
XBRL Definition Linkbase Document
101.LAB
XBRL Labels Linkbase Document
101.PRE
XBRL Presentation Linkbase Document
(1) Filed herewith under Items 1 and 2. Business and Properties.
(*)
Denotes management contract or compensatory plan or arrangement.