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United States

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

 

FORM 10-K

(Mark One)

 

 

 

 

 

ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(D) OF THE SECURITIES EXCHANGE ACT OF 1934

 

FOR THE FISCAL YEAR ENDED December 31, 2017

 

 

 

 

 

 

TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(D) OF THE SECURITIES EXCHANGE ACT OF 1934

 

FOR THE TRANSITION PERIOD OF _________ TO _________.

 

Commission File Number: 001-33905

 

UR-ENERGY INC.

(Exact name of registrant as specified in its charter)

 

 

 

Canada

Not Applicable

State or other jurisdiction of incorporation or organization

(I.R.S. Employer Identification No.)

 

10758 West Centennial Road, Suite 200
Littleton, Colorado 80127
(Address of principal executive offices, including zip code)

 

Registrant’s telephone number, including area code: 720-981-4588

 

Securities registered pursuant to Section 12(b) of the Act:

 

 

 

Title of each class

Name of each exchange on which registered

Common Shares, no par value

NYSE American

 

Securities registered pursuant to Section 12(g) of the Act: None

 

Indicate by check mark if the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act

Yes ☐No ☑

 

Indicate by check mark if the registrant is not required to file reports pursuant to Section 13 or 15(d) of the Exchange Act.  

Yes ☐No ☑

 

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.

Yes ☑No ☐

 

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files).

Yes ☑   No ☐

 

Indicate by check mark if disclosure of delinquent filers pursuant to Item 405 of Regulation S-K (§229.405 of this chapter) is not contained herein, and will not be contained, to the best of registrant’s knowledge, in definitive proxy or information statements incorporated by reference in Part III of this Form 10-K or any amendment to this Form 10-K.  ☐

 

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company, or an emerging growth company. See the definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company,” and “emerging growth company” in Rule 12b-2 of the Exchange Act.

 

 

 

 

 

Large accelerated filer ¨☐

Accelerated filer ☒

Non-accelerated filer ¨☐

Smaller reporting company☐ ¨

 

 

(Do not check if a
smaller reporting company)

Emerging growth company☐ ¨

 

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act.

 

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).

Yes ☐No ☑

 

As of March 1, 2018, there were 145,616,297 shares of the registrant’s no par value Common Shares (“Common Shares”), the registrant’s only outstanding class of voting securities, outstanding. As of June 30, 2017, the aggregate market value of the registrant’s voting Common Shares held by non-affiliates of the registrant was approximately $78.5 million based upon the closing sale price of the Common Shares as reported by the NYSE American. For the purpose of this calculation, the registrant has assumed that its affiliates as of June 30, 2017, included all directors and officers and one shareholder that, collectively, held approximately 21.3 million of its outstanding Common Shares. 

 

DOCUMENTS INCORPORATED BY REFERENCE

Certain information required for Items 10, 11, 12, 13 and 14 of Part III of this Annual Report on Form 10-K is incorporated by reference to the registrant’s definitive proxy statement for the 2018 Annual Meeting of Shareholders.

 

 

 


 

UR-ENERGY INC.

ANNUAL REPORT ON FORM 10-K

 

TABLE OF CONTENTS

 

 

 

 

 

 

 

Page

 

PART I

 

 

 

 

Items 1 and 2. 

Business and Properties

8

Item 1A. 

Risk Factors

29

Item 1B. 

Unresolved Staff Comments

37

Item 3. 

Legal Proceedings

37

Item 4. 

Mine Safety Disclosure

37

 

 

 

 

PART II

 

 

 

 

Item 5. 

Market for Registrant’s Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities

38

Item 6. 

Selected Financial Data

42

Item 7. 

Management’s Discussion and Analysis of Financial Condition and Results of Operations

43

Item 7A. 

Quantitative and Qualitative Disclosures about Market Risk

64

Item 8. 

Financial Statements and Supplementary Data

68

Item 9. 

Changes in and Disagreements with Accountants on Accounting and Financial Disclosure

69

Item 9A. 

Controls and Procedures

69

Item 9B. 

Other Information

70

 

 

 

 

PART III

 

 

 

 

Item 10. 

Directors, Executive Officers and Corporate Governance

71

Item 11. 

Executive Compensation

71

Item 12. 

Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters

71

Item 13. 

Certain Relationships and Related Transactions, and Director Independence

71

Item 14. 

Principal Accounting Fees and Services

71

 

 

 

 

PART IV

 

 

 

 

Item 15. 

Exhibits, Financial Statement Schedules

72

 

Signatures

75

 

 

 

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When we use the terms “Ur-Energy,” “we,” “us,” “our,” or the “Company,” we are referring to Ur-Energy Inc. and its subsidiaries, unless the context otherwise requires. We have included technical terms important to an understanding of our business under “Glossary of Common Terms” at the end of this section. Throughout this document we make statements that are classified as “forward-looking.” Please refer to the “Cautionary Statement Regarding Forward-Looking Statements” section of this document for an explanation of these types of assertions.

 

Cautionary Statement Regarding Forward-Looking Information

 

This annual report on Form 10-K contains "forward-looking statements" within the meaning of applicable United States and Canadian securities laws, and these forward-looking statements can be identified by the use of words such as "expect," "anticipate," "estimate," "believe," "may," "potential," "intends," "plans" and other similar expressions or statements that an action, event or result "may," "could" or "should" be taken, occur or be achieved, or the negative thereof or other similar statements. These statements are only predictions and involve known and unknown risks, uncertainties and other factors which may cause our actual results, performance or achievements, or industry results, to be materially different from any future results, performance, or achievements expressed or implied by these forward-looking statements. Such statements include, but are not limited to: (i) the ability to maintain operations at Lost Creek and timing to determine future development and construction priorities; (ii) the technical and economic viability of Lost Creek; (iii) the timing and outcome of permitting and regulatory approvals of the amendments to the Lost Creek permits and licenses; (iv) the ability to complete additional favorable uranium sales agreements including spot sales if the market warrants and production inventory is available; (v) the production rates and life of the Lost Creek Project and subsequent development of and production from adjoining properties, including LC East; (vi) the potential of exploration targets throughout the Lost Creek Property (including the ability to expand resources); (vii) the potential of our other exploration and development projects, including Shirley Basin, as well as the technical and economic viability of Shirley Basin; (viii) the timing and outcome of applications for regulatory approval to build and operate an in situ recovery mine at Shirley Basin; (ix) the outcome of our forecasts and production projections; (x) the continuing and long-term effects on the uranium market of events that occurred in Japan in 2011 including supply and demand projections; (xi) the outcome of the Department of Commerce Section 232 investigation, including whether the Secretary of Commerce will make a recommendation to the President and the nature of the recommendation,  whether the President will act on the recommendation and, if so, the nature of the action and remedy; (xii) the expected benefits of the proposed remedies in the trade action, including: restoring a sustainable U.S. uranium mining industry and the benefits of a sustainable domestic uranium mining industry to U.S. national security, bolstering national defense, and supporting energy security; and (xiii) the expected impacts on U.S. production and the U.S. uranium mining industry. These other factors include, among others, the following: future estimates for production, development and production operations, capital expenditures, operating costs, mineral resources, recovery rates, grades and market prices; business strategies and measures to implement such strategies; competitive strengths; estimates of goals for expansion and growth of the business and operations; plans and references to our future successes; our history of operating losses and uncertainty of future profitability; status as an exploration stage company; the lack of mineral reserves; risks associated with obtaining permits and other authorizations in the United States; risks associated with current variable economic conditions; our ability to service our debt and maintain compliance with all restrictive covenants related to the debt facility and security documents; the possible impact of future financings; the hazards associated with mining production; compliance with environmental laws and regulations; uncertainty regarding the pricing and collection of accounts; the possibility for adverse results in potential litigation; uncertainties associated with changes in government policy and regulation; uncertainties associated with a Canada Revenue Agency or U.S. Internal Revenue Service audit of any of our cross border transactions; adverse changes in general business conditions in any of the countries in which we do business; changes in size and structure; the effectiveness of management and our strategic relationships; ability to attract and retain key

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personnel; uncertainties regarding the need for additional capital; uncertainty regarding the fluctuations of quarterly results; foreign currency exchange risks; ability to enforce civil liabilities under U.S. securities laws outside the United States; ability to maintain our listing on the NYSE American LLC (“NYSE American”) and Toronto Stock Exchange (“TSX”); risks associated with the expected classification as a "passive foreign investment company" under the applicable provisions of the U.S. Internal Revenue Code of 1986, as amended; risks associated with our investments and other risks and uncertainties described under the heading “Risk Factors” of this annual report.

 

Cautionary Note to U.S. Investors Concerning Disclosure of Mineral Resources

 

Unless otherwise indicated, all resource estimates included in this Form 10-K have been prepared in accordance with Canadian National Instrument 43-101 Standards of Disclosure for Mineral Projects (“NI 43-101”) and the Canadian Institute of Mining, Metallurgy and Petroleum Definition Standards for Mineral Resources and Mineral Reserves (“CIM Definition Standards”). NI 43-101 is a rule developed by the Canadian Securities Administrators which establishes standards for all public disclosure an issuer makes of scientific and technical information concerning mineral projects. NI 43-101 permits the disclosure of an historical estimate made prior to the adoption of NI 43-101 that does not comply with NI 43-101 to be disclosed using the historical terminology if the disclosure: (a) identifies the source and date of the historical estimate; (b) comments on the relevance and reliability of the historical estimate; (c) to the extent known, provides the key assumptions, parameters and methods used to prepare the historical estimate; (d) states whether the historical estimate uses categories other than those prescribed by NI 43-101; and (e) includes any more recent estimates or data available. 

 

Canadian standards, including NI 43-101, differ significantly from the requirements of the United States Securities and Exchange Commission (“SEC”), and resource information contained in this Form 10-K may not be comparable to similar information disclosed by U.S. companies. In particular, the term “resource” does not equate to the term “‘reserves.” Under SEC Industry Guide 7, mineralization may not be classified as a “reserve” unless the determination has been made that the mineralization could be economically and legally produced or extracted at the time the reserve determination is made. SEC Industry Guide 7 does not define and the SEC’s disclosure standards normally do not permit the inclusion of information concerning “measured mineral resources,” “indicated mineral resources” or “inferred mineral resources” or other descriptions of the amount of mineralization in mineral deposits that do not constitute “reserves” by U.S. standards in documents filed with the SEC. U.S. investors should also understand that “inferred mineral resources” have a great amount of uncertainty as to their existence and great uncertainty as to their economic and legal feasibility. It cannot be assumed that all or any part of an “inferred mineral resource” will ever be upgraded to a higher category. Under Canadian rules, estimated “inferred mineral resources” may not form the basis of feasibility or pre-feasibility studies except in rare cases. Investors are cautioned not to assume that all or any part of an “inferred mineral resource” exists or is economically or legally mineable. Disclosure of “contained ounces” in a resource is permitted disclosure under Canadian regulations; however, the SEC normally only permits issuers to report mineralization that does not constitute “reserves” by SEC standards as in-place tonnage and grade without reference to unit measures. Accordingly, information concerning mineral deposits set forth herein may not be comparable to information made public by companies that report in accordance with U.S. standards.

 

NI 43-101 Review of Technical Information: James A. Bonner, Ur-Energy Vice President Geology, P.Geo. and Qualified Person as defined by NI 43-101, reviewed and approved the technical information contained in this Annual Report.

 

4


 

Glossary of Common Terms and Abbreviations

 

 

 

Mineral Resource 

is a concentration or occurrence of solid material of economic interest in or on the Earth’s crust in such form, grade or quality and quantity that there are reasonable prospects for eventual economic extraction. The location, quantity, grade or quality, continuity and other geological characteristics of a Mineral Resource are known, estimated or interpreted from specific geological evidence and knowledge, including sampling. CIM Definition Standards; NI 43-101, Section 1.1.

 

 

Inferred Mineral Resource

is that part of a Mineral Resource for which quantity and grade or quality are estimated on the basis of limited geological evidence and sampling. Geologic evidence is sufficient to imply but not verify geological and grade or quality continuity. An Inferred Mineral Resource has a lower level of confidence than that applying to an Indicated Mineral Resource and must not be converted to a Mineral Reserve. It is reasonably expected that the majority of Inferred Mineral Resources could be upgraded to Indicated Mineral Resources with continued exploration.  CIM Definition Standards; NI 43-101, Section 1.1.

 

 

Indicated Mineral Resource

is that part of a Mineral Resource for which quantity, grade or quality, densities, shape and physical characteristics are estimated with sufficient confidence to allow the application of Modifying Factors in sufficient detail to support mine planning and evaluation of the economic viability of the deposit. Geological evidence is derived from adequately detailed and reliable exploration, sampling and testing and is sufficient to assume geological and grade or quality continuity between points of observation. An Indicated Mineral Resource has a lower level of confidence than that applying to a Measured Mineral Resource and may only be converted to a Probable Mineral Reserve. CIM Definition Standards; NI 43-101, Section 1.1.

 

 

Measured Mineral Resource

is that part of a Mineral Resource for which quantity, grade or quality, densities, shape, and physical characteristics are estimated with confidence sufficient to allow the application of Modifying Factors to support detailed mine planning and final evaluation of the economic viability of the deposit. Geological evidence is derived from detailed and reliable exploration, sampling and testing and is sufficient to confirm geological and grade or quality continuity between points of observation. A Measured Mineral Resource has a higher level of confidence than that applying to either an Indicated Mineral Resource or an Inferred Mineral Resource. It may be converted to a Proven Mineral Reserve or to a Probable Mineral Reserve. CIM Definition Standards; NI 43‑101, Section 1.1.

 

 

Cut-off or cut-off grade

when determining economically viable mineral resources, the lowest grade of mineralized material that can be mined

 

 

Formation

a distinct layer of sedimentary or volcanic rock of similar composition

 

 

Grade

Quantity or percentage of metal per unit weight of host rock

 

 

Host Rock

the rock containing a mineral or an ore body

 

 

Modifying Factors

are considerations used to convert Mineral Resources to Mineral Reserves. These include, but are not restricted to, mining, processing, metallurgical, infrastructure, economic, marketing, legal, environmental, social and governmental factors. CIM Definition Standards

5


 

 

 

Lithology

is a description of a rock; generally, its physical nature. The description would address such things as grain size, texture, rounding, and even chemical composition. A lithologic description would be: coarse grained well-rounded quartz sandstone with 10% pink feldspar and 1% muscovite.

 

 

Mineral

a naturally formed chemical element or compound having a definite chemical composition and, usually, a characteristic crystal form.

 

 

Mineralization

a natural occurrence, in rocks or soil, of one or more metal yielding minerals

 

 

Outcrop

is that part of a geologic formation or structure that appears at the surface of the Earth.

 

 

PFN 

is a modern geologic logging method known as Prompt Fission Neutron. PFN is considered a direct measurement of true uranium concentration (% U) and is used to verify the grades of mineral intercepts previously reported by gamma logging. PFN logging is accomplished by a down-hole probe in much the same manner as gamma logs, however, only the mineralized interval plus a buffer interval above and below are logged.

 

 

Preliminary Economic

Assessment (or PEA)

A Preliminary Economic Assessment performed under NI 43-101. A Preliminary Economic Assessment is a study, other than a prefeasibility study or feasibility study, which includes an economic analysis of the potential viability of mineral resources.

 

 

 

Reclamation

is the process by which lands disturbed as a result of mineral extraction activities are modified to support beneficial land use. Reclamation activity may include the removal of buildings, equipment, machinery, and other physical remnants of mining activities, closure of tailings storage facilities, leach pads, and other features, and contouring, covering and re-vegetation of waste rock, and other disturbed areas.

 

 

Uranium

a heavy, naturally radioactive, metallic element of atomic number 92. Uranium in its pure form is a heavy metal. Its two principal isotopes are U-238 and U-235, of which U-235 is the necessary component for the nuclear fuel cycle. However, “uranium” used in this Annual Report refers to triuranium octoxide, also called “U3O8” or “yellowcake”, and is produced from uranium deposits. It is the most actively traded

uranium-related commodity.

 

 

Uranium concentrate

a yellowish to yellow-brownish powder obtained from the chemical processing of uranium-bearing material. Uranium concentrate typically contains 70% to 90% U3O8 by weight. Uranium concentrate is also referred to as “yellowcake.”

 

 

 

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Abbreviations:

 

 

BLM

U.S. Bureau of Land Management

CERCLA

Comprehensive Environmental Response and Liability Act

CIM

Canadian Institute of Mining, Metallurgy and Petroleum

DDW

Deep Disposal Well

DOC

U.S. Department of Commerce

eU3O8

Equivalent U3O8 as measured by a calibrated gamma instrument

EMT

East Mineral Trend, located within our LC East Project (Great Divide Basin, Wyoming)

EPA

U.S. Environmental Protection Agency

GDB

Great Divide Basin, Wyoming

GPM

Gallons per minute

GT

Grade x Thickness product (% ft.) of a mineral intercept (expressed without units)

HH

Header house

IX

Ion Exchange

ISR

In Situ Recovery (literally, ‘in place’ recovery) (also known as in situ leach or ISL)

LT

Long-term (as relates to long-term pricing in the uranium market)

MMT

Main Mineral Trend, located within our Lost Creek Project (Great Divide Basin, Wyoming)

MU

Mine Unit (also referred to as wellfield)

NEPA

U.S. National Environmental Policy Act

NI 43-101

Canadian National Instrument 43-101 (Standards of Disclosure for Mineral Properties)

NRC

U.S. Nuclear Regulatory Commission

PEA

Preliminary Economic Assessment

PPM

Parts per million

RCRA

Resource Conservation and Recovery Act

SEC

U.S. Securities Exchange Commission

UIC

Underground Injection Control (pursuant to U.S. Environmental Protection Agency regulations)

U3O8

A standard chemical formula commonly used to express the natural form of uranium mineralization.  U represents uranium and O represents oxygen.

URP

Wyoming Uranium Recovery Program (WDEQ Program name for Agreement State Program under development)

USFWS

U.S. Fish and Wildlife Service

WDEQ

Wyoming Department of Environmental Quality (and its various divisions, LQD/Land Quality Division, WQD/Water Quality Division; AQD/Air Quality Division; and SHWD/Solid and Hazardous Waste Division)

WEQC

Wyoming Environmental Quality Council

WGFD

Wyoming Game and Fish Department

 

Metric/Imperial Conversion Table

 

The imperial equivalents of the metric units of measurement used in this annual report are as follows:

 

 

 

 

 

 

Imperial Measure

Metric Unit

 Metric Unit

Imperial Measure

2.4711 acres

1 hectare

0.4047 hectares

1 acre

2.2046 pounds

1 kilogram

0.4536 kilograms

1 pound

0.6214 miles

1 kilometer

1.6093 kilometers

1 mile

3.2808 feet

1 meter

0.3048 meters

1 foot

1.1023 short tons

1 tonne

0.9072 tonnes

1 short ton

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Reporting Currency

 

All amounts in this report are expressed in United States (U.S.) dollars, unless otherwise indicated. The Financial Statements are presented in accordance with accounting principles generally accepted in the United States.

 

PART  I

 

Items 1 and 2.  BUSINESS AND PROPERTIES

 

Overview and Corporate Structure

 

Incorporated on March 22, 2004, Ur-Energy is an exploration stage mining company, as that term is defined in Securities and Exchange Commission (“SEC”) Industry Guide 7.  We are engaged in uranium mining, recovery and processing activities, including the acquisition, exploration, development and operation of uranium mineral properties in the United States. Through our Wyoming operating subsidiary, Lost Creek ISR, LLC, we began operation of our first in situ recovery uranium mine 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 TSX under the symbol “URE” and on the NYSE American under the symbol “URG.”

 

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: NFU Wyoming, LLC (“NFU Wyoming”), a limited liability company formed under the laws of the State of Wyoming to facilitate acquisition of certain property and assets and, currently, to act as our land holding and exploration entity; 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; 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.

 

Ur-Energy USA has two jointly held subsidiaries with NFU Wyoming: NFUR Bootheel, LLC (“NFUR Bootheel”), a limited liability company formed under the laws of the State of Colorado to facilitate participation in a venture project at our Bootheel Project; and NFUR Hauber, LLC (“NFUR Hauber”), a limited liability company formed under the laws of the State of Colorado to facilitate participation in a venture project at our Hauber project.

 

NFUR Hauber has one wholly-owned subsidiary: Hauber Project LLC, a limited liability company formed under the laws of the State of Colorado to hold our Hauber project. NFUR Hauber is the sole member and manager of Hauber Project LLC.

 

NFUR Bootheel holds an interest in The Bootheel Project, LLC, a limited liability company formed under the laws of the State of Colorado to hold the Bootheel property (and, formerly, the Buck Point property), a venture with Canada Jetlines Ltd. (formerly, Jet Metal Corp.), in which, at December 31, 2017, we own a 19.115% interest.

 

8


 

Currently, and at December 31, 2017, our principal direct and indirect subsidiaries, and affiliated entities, and the jurisdictions in which they were incorporated or organized, are as follows:

 

Picture 1

 

We are engaged in uranium mining, recovery and processing operations, in addition to the exploration and development of uranium mineral properties. Our wholly-owned Lost Creek Project in Sweetwater County, Wyoming is our flagship 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 production from Lost Creek were made in December 2013.

 

Currently, we have 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. Combined, these multi-year sales agreements represent a significant portion of our anticipated production into 2021. These agreements, individually, do not represent a substantial portion of our annual projected production, and our business is therefore not substantially dependent upon any one of the agreements.

 

We are contractually committed to sell 470,000 pounds of uranium yellowcake during 2018, at an average price of approximately $49 per pound. During 2017, we worked with our customers to establish our delivery schedule for these 2018 commitments, with distribution of sales in the first half of the year. This schedule was created to avoid uneven cash flows that could result from uneven delivery schedules. Subsequently, we have taken advantage of the low prices in 2017 to enter into purchase agreements for delivery of 460,000 pounds of uranium yellowcake into those contractual commitments. The average cost of the purchases is $24 per pound. We have already delivered a portion of the pounds and are scheduled to deliver the remaining pounds in the first half of the year, as further detailed below.

 

9


 

Our other material asset, Shirley Basin, is one of the assets we acquired as a part of the Pathfinder transaction which closed in December 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. Baseline studies necessary for the permitting and licensing of the project commenced in 2014 and were completed in 2015. In December 2015, our application for a permit to mine was submitted to the State of Wyoming Department of Environmental Quality (“WDEQ”).

 

Work is well underway on other applications for all necessary authorizations to mine at Shirley Basin. We have monitored the development of the Wyoming “agreement state” program, by which the NRC will delegate its authority for source material licensure and other radiation safety issues to the WDEQ. We understand that the development of the Uranium Recovery Program (“URP”) remains on schedule for full implementation and transition likely occurring in 2018, following Wyoming’s final, formal, submission of its program for approval by the NRC (November 14, 2017). This formal request includes WDEQ’s target date to become an Agreement State: September 30, 2018. Based upon that timing, we currently anticipate submitting our application for a source material license for Shirley Basin to the State URP.

We utilize in situ recovery of the uranium at Lost Creek and will do so at other projects where this is possible. The ISR technique is employed in uranium extraction because it allows for a lower cost and effective recovery of roll front mineralization. The in situ technique does not require the installation of tailings facilities or significant surface disturbance. This mining 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, sodium bicarbonate as a complexing agent, and carbon dioxide for pH control. 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 complexing agent and sent back to the wellfield to recover additional uranium. A low-volume bleed is permanently removed from the lixiviant flow. A reverse osmosis (“RO”) process is available to minimize the waste water 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 dozens of injection and production wells installed in patterns to optimize the areal sweep of fluid through the uranium ore body.

 

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 dual processing trains with separate elution, precipitation, filter press and drying circuits (this is in contrast to 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 a RO unit was installed during initial construction to complete groundwater restoration once mining is complete.

 

The elution circuit (the first step after ion exchange) is utilized to transfer the uranium from the IX resin and concentrate it 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

10


 

to a yellowcake dryer, which will further reduce the moisture content, yielding the final dried, free-flowing, product. Refined, salable yellowcake is packaged in 55-gallon steel drums. 

 

The restoration circuit may be utilized in the production as well as the post-mining phases of the operation. The RO may initially be utilized as a part of our Class V recycling circuit to minimize the waste water stream generated during production. Once production is complete, the groundwater must be restored to its pre-mining class of use by removing a small portion of the groundwater and disposing of it (commonly known as sweep). Following sweep, the groundwater is treated utilizing RO and re-injecting the clean water. Finally, the groundwater is homogenized and sampled to insure the cleanup is complete, thus ending the mining process.

 

Our Lost Creek processing facility was constructed during 2012 – 2013, with production operations commencing in August 2013. Our first sales were made in December 2013. Nameplate design and NRC-licensed capacity of our Lost Creek processing plant is two million pounds per year, of which approximately one million pounds per year may be produced from our 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. Production of refined yellowcake was 254,012 pounds and 561,094 pounds in 2017 and 2016, respectively. 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 permit us to process uranium from other of our 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 in situ uranium mine sites in the region. This design would permit 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.

 

Our Lost Creek processing facility includes all circuits for the production, drying and packaging of uranium yellowcake for delivery into sales. As contemplated in the Preliminary Economic Assessment of Shirley Basin, we expect that the Lost Creek processing facility may be utilized for the drying and packaging of uranium from Shirley Basin, for which we currently anticipate the need only for a satellite plant. However, the Shirley Basin permit application contemplates the construction of a full processing facility, providing greater construction and operating flexibility as may be dictated by market conditions.

 

Our Mineral Properties

 

Our current land portfolio in Wyoming includes 13 projects. Eleven of these projects are in the Great Divide Basin, Wyoming, including our flagship project, Lost Creek Project, which began production operations in August 2013. Currently we control more than 1,900 unpatented mining claims and three State of Wyoming mineral leases for a total of more than 37,500 acres (~15,500 hectares) in the area of the Lost Creek Property, including the Lost Creek permit area (the “Lost Creek Project” or “Lost Creek”) and certain adjoining properties 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 NI 43-101 compliant mineral resources: Lost Creek, LC East, LC West, LC South and LC North.  See Resource Summary

11


 

below in Updated Preliminary Economic Assessment for Lost Creek Property. Below is a map showing our Wyoming projects and the geologic basins in which they are located.

 

\\ure-exchange\public\GIS\Presentations\2014\Penne_Feb\WY_PropLocations_20140228.jpg

 

Our Wyoming properties together total more than 55,000 acres (approximately 22,250 hectares) and include two properties, Shirley Basin and Lucky Mc, obtained through our 2013 acquisition of Pathfinder Mines Corporation. That acquisition also included a significant exploration and development database compiled by Pathfinder over several decades, which provided the initial lead from which we acquired a gold exploration project in west-central Nevada (the “Excel Project”) in 2017. To date, the project comprises 102 federal lode mining claims for a property position of approximately 2,100 acres. The Excel Project is located within the Excelsior Mountains, in proximity to the Camp Douglas and Candelaria Mining Districts.

12


 

Operating Properties

 

Lost Creek Project – Great Divide Basin, Wyoming

 

The Lost Creek Project area was acquired in 2005, and is located in the Great Divide Basin, Wyoming. The Main Mineral Trend of the Lost Creek uranium deposit (the “MMT”) is located within the Lost Creek Project. 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 off of Sweetwater County Road 23N (Wamsutter-Crooks Gap Road); the other enters from the east off of U.S. Bureau of Land Management (“BLM”) Sooner Road. On a wider basis, from population centers, the 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 Lost Creek Property is located as shown here:

C:\Users\penne.goplerud\AppData\Local\Microsoft\Windows\Temporary Internet Files\Content.Outlook\FR7Q334L\2018 (002).jpg

 

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

13


 

overhead electrical service is aligned in a north-to-south direction along the western boundary of the Lost Creek Project. A new 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 expand the wellfield operations.

 

Following the purchase of an existing production royalty with respect to 20 claims of the Lost Creek Project in 2013, there are no remaining royalties at the Lost Creek Project, except for the royalty on the State of Wyoming section mineral lease as provided by law. Currently, there is only limited production planned from the State lease section. There is a production royalty of one percent on certain claims of the LC East Project, and other royalties on other claims within the other adjoining projects (LC South and EN projects) as well as the other State sections on which we maintain mineral leases (LC West and EN projects).

 

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, warehouse building, and drill shed building.  In August 2013 we were given operational approval by the NRC and commenced production operation activities. See also discussion of the operational methods used at Lost Creek, above, under heading “Business and Properties.”

 

For the Lost Creek PEA, in order to accurately reflect existing resources, all resources produced through September 30, 2015 (1,358,407 pounds) were subtracted from total Measured Resources from the HJ Horizon in Mine Unit 1 (“MU1”). All the wells to support the originally-planned 13 header houses (“HHs”) have been completed. HHs 1-1 through 1-11 were operational as of the effective date of the Lost Creek PEA, October 15, 2015. Subsequently, the last two of the originally-planned header houses in MU1 were brought online (HH 1-12 (November 2015) and HH 1-13 (May 2016)).

 

All monitor ring wells in Mine Unit 2 (“MU2”) have been installed, pump-tested and approved for operational use. As of October 15, 2015, the effective date for the Lost Creek PEA, 138 pattern wells were piloted within HHs 2-1, 2-2 and 2-3. In a limited development program in 2017, the wells previously piloted were completed for use as well as construction of HHs 2-2 and 2-3.  HH 2-2 was brought into operation in August 2017 and HH 2-3 started in January 2018. HH 2-1 construction is expected to be complete in 2018 Q1, at which time it will be brought online.

 

During 2017, with production controlled at lower levels, 265,391 pounds of U3O8 were captured within the Lost Creek plant; 254,012 pounds U3O8  were packaged in drums; and 257,213 pounds U3O8  of drummed inventory were shipped from the Lost Creek processing plant to the converter. At December 31, 2017, inventory at the conversion facility was approximately 94,077 pounds U3O8

 

From production, Lost Creek sold 261,000 pounds U3O8  during calendar 2017. Overall, we sold 780,000 pounds of yellowcake into contractual commitments in 2017 at an average price of $49.09 per pound.

 

After more than four years of operations, the 2017 average plant head grade remained at 28 ppm, with an average head grade for the fourth quarter of 29 ppm, after operations began in MU2. The lower head grades in MU1, as well as varying month-to-month grades, is a typical result as the mine matures and older operating patterns remain in the flow regime while newer patterns are brought online.

 

14


 

Updated Preliminary Economic Assessment for Lost Creek Property

 

In 2016, we issued an updated Preliminary Economic Assessment for the Lost Creek Property Sweetwater County Wyoming, as amended (February 8, 2016 (TREC, Inc.)) (the “Lost Creek PEA”). The Lost Creek PEA was prepared for the Company and its subsidiary, Lost Creek ISR, LLC, by Douglass H. Graves, P.E., TREC, Inc. (“TREC”) and James A. Bonner, P.Geo., Vice President Geology of the Company in accordance with NI 43-101.

 

According to the Lost Creek PEA, the mineral resources at the Lost Creek Property at the date of the report were as follows:

 

Lost Creek Property - Resource Summary

 

 

 

 

 

 

 

 

 

 

 

 

 

 

MEASURED

  

INDICATED

  

INFERRED

PROJECT

AVG GRADE

SHORT TONS

POUNDS

 

AVG GRADE

SHORT TONS

POUNDS

 

AVG GRADE

SHORT TONS

POUNDS

 

% eU3O8

(X 1000)

(X 1000)

 

% eU3O8

(X 1000)

(X 1000)

 

% eU3O8

(X 1000)

(X 1000)

LOST CREEK

0.048

8,339

7,937

 

0.046

3,831

3,491

 

0.046

3,116

2,844

MU1 production through 9/30/15

(0.048)

(1,415)

(1,358)

 

 

 

 

 

 

 

 

LC EAST

0.052

1,392

1,449

 

0.041

1,891

1,567

 

0.042

2,954

2,484

LC NORTH

-----

-----

-----

 

-----

-----

-----

 

0.045

645

581

LC SOUTH

-----

-----

-----

 

0.037

220

165

 

0.039

637

496

LC WEST

-----

-----

-----

 

-----

-----

-----

 

0.109

16

34

EN

-----

-----

-----

 

-----

-----

-----

 

-----

-----

-----

GRAND TOTAL

0.048

8,316

8,028

 

0.044

5,942

5,223

 

0.044

7,368

6,439

 

 

 

 

 

 

 

 

 

 

 

 

 

 

MEASURED + INDICATED =

14,258

13,251

 

 

 

 

 

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.

Measured, Indicated, and Inferred Mineral Resources as defined in Section 1.2 of NI 43-101 (the CIM Definition Standards (CIM Council, 2014)).

5.

Resources are reported through October 15, 2015.

6.

All reported resources occur below the static water table.

7.

1,358,407 lbs. of uranium have been produced from the HJ Horizon in MU1 (Lost Creek Project) as of September 30, 2015.

8.

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

 

Information shown in the table above differs from the disclosure requirements of the SEC.  See Cautionary Note to U.S. Investors Concerning Disclosure of Mineral Resources, above.

 

 

The Lost Creek PEA discloses changes for the Lost Creek Property which come in the form of an updated mineral resource estimate prompted by recent drilling within Lost Creek’s MU2, exploratory drilling at the Lost Creek and LC East Projects, and the re-estimation of all previously-identified resources for the Property at a revised 0.20 grade-thickness (GT) cut-off. The economic analyses within the Lost Creek PEA have been revised to evaluate the impact of additional identified resources with information and data acquired through two years of ISR operations at Lost Creek. The Lost Creek PEA therefore serves to replace the last economic analyses for

15


 

the Lost Creek Property from December 2013 and the NI 43-101 Technical Report on the Lost Creek Property, dated June 17, 2015 (the “2015 Technical Report”). The Lost Creek PEA covers production through September 30, 2015 and drilling and other exploration and operational activities conducted through October 15, 2015.

 

We published the 2015 Technical Report for the Lost Creek Property to report increased resources for its operating MU1 and from exploration drilling conducted early in 2015. In order to reconcile higher-than-expected uranium recoveries from production operations in this mine unit, various analyses were conducted. These analyses, including detailed remapping of mineralized trends within ten sand horizons and interpretation of data from an additional 85 closely-spaced wells and core-holes, resulted in the re-estimation of the mineral resources and the conclusion that it was most appropriate to lower the grade-thickness (“GT”) cut-offs from 0.30 to 0.20 within our GT contouring resource estimation technique.  Employing these revised guidelines, resources for MU1 were re-mapped and re-evaluated, increasing the MU1 Measured Resources by 55% (after subtraction of MU1 production). Through the monitoring of continued production from MU1, the authors believe the 0.20 GT cutoff better represents the uranium resources for the Lost Creek Property, and is supported by the economic analysis included in the PEA as well as the actual production achieved at the property to date. Accordingly, for the Lost Creek PEA, all resource estimations for Lost Creek Property have used the new 0.20 GT cutoff, again, following re-mapping and re-evaluation. Between the 2015 Technical Report and the Lost Creek PEA’s publication, our activities resulted in a cumulative increase of mineral resources at the Lost Creek Property of 31% in the Measured and Indicated categories and 28% in the Inferred category as was then reported in the Lost Creek PEA.

 

The Lost Creek Property represents the composite of six individual 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. 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 Lost Creek PEA mineral resource estimate includes drill data and analyses of approximately 3,200 historic and current holes and over 1.8 million feet of drilling at the Lost Creek Project alone. With the acquisition of the Lost Creek Project, we acquired logs and analyses from 569 historic holes representing 366,268 feet of data. Since our acquisition of the project we have drilled 2,629 holes and wells including the construction and development drilling during 2013-2016 for MU1 and initial work in MU2 at Lost Creek. Drilling at Lost Creek through October 15, 2015 was included in the PEA. Additionally, drilling from the other five projects at the Lost Creek Property, both historic and our drill programs, is included in the mineral resource estimate. Collectively, this represents an additional 2,387 drill holes (1,306,331 feet). 

 

The Lost Creek PEA is the first technical report prepared since production operations began at Lost Creek which includes an updated preliminary economic assessment. It reflects the reported production from August 3, 2013 to September 30, 2015 and subtracts that amount (1,358,407 pounds) when summing the Measured Resources. Since September 30, 2015, and up through December 31, 2017, another 1,015,079 pounds have been produced. Total production from both MU1 and MU2, through December 31, 2017, equaled 2,373,486 pounds and the remaining Lost Creek PEA resources following that production are detailed below: 

 

 

 

 

16


 

 

 

 

 

 

 

 

 

 

 

 

 

12/31/17 Reconciliation of Lost Creek Property Resource Estimate

MEASURED

 

INDICATED

 

INFERRED

PROJECT

AVG GRADE

SHORT TONS

POUNDS

 

AVG GRADE

SHORT TONS

POUNDS

 

AVG GRADE

SHORT TONS

POUNDS

 

% eU3O8

(X 1000)

(X 1000)

 

% eU3O8

(X 1000)

(X 1000)

 

% eU3O8

(X 1000)

(X 1000)

LOST CREEK

0.048

8,339

7,937

 

0.046

3,831

3,491

 

0.046

3,116

2,844

MU1 production through 9/30/15

(0.048)

(1,415)

(1,358)

 

 

 

 

 

 

 

 

LC production 9/30/15 - 12/31/17

(0.048)

(1,057)

(1,015)

 

 

 

 

 

 

 

 

Lost Creek Subtotal at 12/31/17

0.048

5,867

5,564

 

0.046

3,831

3,491

 

0.046

3,116

2,844

 

 

 

 

 

 

 

 

 

 

 

 

LC EAST

0.052

1,392

1,449

 

0.041

1,891

1,567

 

0.042

2,954

2,484

LC NORTH

-----

-----

-----

 

-----

-----

-----

 

0.045

645

581

LC SOUTH

-----

-----

-----

 

0.037

220

165

 

0.039

637

496

LC WEST

-----

-----

-----

 

-----

-----

-----

 

0.109

16

34

EN

-----

-----

-----

 

-----

-----

-----

 

-----

-----

-----

Grand Total at 12/31/17

0.048

7,259

7,013

 

0.044

5,942

5,223

 

0.044

7,368

6,439

 

 

 

 

 

 

 

 

 

 

 

 

 

 

MEASURED + INDICATED =

13,201

12,236

 

 

 

 

 

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 (received August 2011); a Plan of Operations with the BLM (Record of Decision (“ROD”)) received October 2012; affirmed by U.S. District Court for the District of Wyoming, September 2013); and a Permit and License to Mine from the WDEQ (October 2011).  The WDEQ License to Mine was issued following determinations in favor of the project by the WEQC with respect to a third-party objection, which included a WEQC direction that the WDEQ Permit be approved by the WDEQ.  The WDEQ Permit includes the approval of the first mine unit, 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 may include changes in the designation of the 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. In September 2015, the USFWS issued its finding that the greater sage grouse does not warrant protection under the Endangered Species Act (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 now or 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.

 

The State of Wyoming has developed a “core-area strategy” to help protect the greater sage-grouse species within certain core areas of the state. Exploration areas of our Lost Creek property are all within a designated core area and are thus subject to work activity restrictions from March 1 to July 15 of each year.  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 the Lost Creek Project are somewhat different because the State has recognized that mining projects within core areas

17


 

must be allowed to operate year-round. Therefore, there are no timing restrictions on drilling, construction, or operational activities within pre-approved disturbed areas within our permit to mine.

 

Meanwhile, in related regulatory processes, the BLM prepared and issued, in September 2015, environmental impact statements for and issued amendments to eleven Resource Management Plans (“RMPs”), related to the greater sage-grouse. Included in these RMPs were proposals to designate millions of acres of federal lands currently open for mineral location as lands to be withdrawn from such mineral status. The BLM has subsequently, in 2017, cancelled the withdrawal proposal.

 

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. The latter permit allows Lost Creek to operate up to five 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.

 

In 2014, two applications for amendments to the primary authorizations to mine at Lost Creek were submitted to federal regulatory agencies, NRC and BLM, for the development and mining of LC East Project and the KM Horizon at Lost Creek. In 2015, the BLM issued a notice of intent to complete an environmental impact statement for the application. The NRC is participating in this review as a cooperating agency. A permit amendment requesting approval to mine at the LC East Project and within the KM Horizon at the Lost Creek Project was also submitted to the WDEQ. Approval will include an aquifer exemption. The air quality permit will be revised to account for additional surface disturbance. An application will be submitted to Sweetwater County to re-zone the land at LC East. A subsequent Development Plan will also have to be submitted for review and approval. Numerous well permits from the State Engineer’s Office will be required.

 

At this time, those applications continue through the regulatory process, except we have recently withdrawn the application insofar as it relates to two of the eleven projected mine units – those for the KM Horizon at Lost Creek. This change should not delay the completion of the permitting process with respect to the LC East Project (nine mine units total).  It is anticipated that permits and authorizations will be completed in 2018.

 

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 recirculation of fresh permeate (i.e., clean water) into relatively shallow Class V wells. Site operators use the reverse osmosis circuits, which were installed during initial construction of the plant, to treat process waste water 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 are expected to significantly enhance waste water 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 certain of our subsidiaries, 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 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 Sweetwater County Recorder attesting to the payment 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.

 

18


 

The surface of all the 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 the State of Wyoming mineral lease.  The state lease at the Lost Creek Project requires a nominal surface impact fee to be paid. The other state mineral leases currently do not have surface impact payment obligations. 

 

Exploration and Development Properties

 

Our Five Projects Adjoining Lost Creek Together with the Lost Creek Project Form the Lost Creek Property

 

The LC East and LC West Projects (currently, approximately 5,710 acres (2,310 hectares) and 3,840 acres (1,554 hectares), respectively) were added to the Lost Creek Property in 2012. The two projects were formed through location of new unpatented lode mining claims and an asset exchange completed in February 2012 with Uranium One Americas, Inc., through which we acquired 175 unpatented mining claims and related data. In 2012, all baseline studies at LC East were initiated. As discussed above, in 2014, we submitted applications for amendments of the Lost Creek licenses and permits to include development of LC East. We also located additional lode mining claims to secure the lands in what will be the LC East permit area. The East Mineral Trend (the “EMT”) is a second mineral trend of significance, in addition to the MMT at Lost Creek, identified by historic drilling on the lands forming LC East.  Although geologically similar, it appears to be a separate and independent trend from the MMT.  The Lost Creek PEA contains a recommendation that delineation drilling of identified resources in the EMT continue, together with progressing all necessary permit and license amendments to permit future production. 

 

The LC North Project (approximately 7,730 acres (3,120 hectares)) 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 in the future to pursue the potential of an extension of the MMT in the HJ and KM horizons.

 

The LC South Project (approximately 10,775 acres (4,360 hectares)) 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 (30,867 meters)) 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. In the future, we may conduct additional drilling to further evaluate the potential of deeper mineralization.

 

The EN Project (approximately 5,500 acres (~ 2,200 hectares)) is adjacent to and east of LC South. We have over 50 historical drill logs from the EN project. Some minimal, deep, exploration drilling has been conducted at the project. Although no mineral resource is yet reported due to the limited nature of the data, we may in the future explore this area further with wide spaced framework drilling to assess regional alteration and stratigraphic relationships. During 2016, in an effort to contain costs, we reduced the number of federal mining claims and state mineral leases held at the EN project.

 

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 the early 1950s after the Gas Hills District discoveries, and continued to increase in the 1960s, with

19


 

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 (Amax), 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 Main Mineral Trend (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 8 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, LLC. In June 2005, Ur-Energy USA purchased 100% ownership of NFU Wyoming, LLC.

 

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 deposits in the GDB are found principally in the Battle Spring Formation, which hosts the Lost Creek Project 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.

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We occasionally perform leach testing on various samples from the Lost Creek Project.  Most recently, in 2010, we performed leach testing on samples from the KM Horizon of the Lost Creek Project. Seven samples obtained from one-foot sections of core were tested for mineral recovery using the same test methods as in prior tests from the HJ Horizon (currently licensed for production at Lost Creek, and being recovered in MU1). Twenty-five pore volumes of various bicarbonate leach solutions were passed through the samples. Uranium recovery ranged from 54.1 to 93.0% with an average uranium recovery of 80.6%. These results are similar to earlier leaching and recovery tests conducted on behalf of the Company on samples from the HJ Horizon, which returned results consistently averaging 82 – 83%. We believe these results are consistent with industry experience.

 

Pathfinder Mines Corporation:  Shirley Basin Mine Site (Shirley Basin, Wyoming) and Lucky Mc Mine Site (Gas Hills Mine District, Wyoming)

 

As a part of the Pathfinder acquisition, we now own the Shirley Basin and Lucky Mc mine sites in the Shirley Basin and Gas Hills mining districts of Wyoming, respectively, from which Pathfinder and its predecessors historically produced more than seventy-one million pounds of uranium, primarily from the 1960s through the 1990s. Pathfinder’s predecessors included COGEMA, Lucky Mc Uranium Corporation, and Utah Construction/Utah International.

 

Both Lucky Mc and Shirley Basin conventional mine operations were suspended in the 1990s due to low uranium pricing, and facility reclamation was substantially completed. We assumed the remaining reclamation responsibilities including financial surety for reclamation, at Shirley Basin and at the Lucky Mc mine site. The Lucky Mc tailings site was fully reclaimed and, at the time of our acquisition, was in the process of being transferred to the U.S. Department of Energy. Therefore, we assumed no obligations with respect to the Lucky Mc tailings site, which were retained by the seller upon closing, or the NRC license at the site.  We do not have plans for the further exploration or development of the Lucky Mc property during 2018.

 

Together with property holdings of patented lands, unpatented mining claims, and State of Wyoming and private leases totalling more than 5,500 acres (nearly 3,700 acres at Shirley Basin (approximately 1,500 hectares); approximately 1,800 at Lucky Mc (approximately 750 hectares)), we also acquired all historic geologic, engineering and operational data related to the two mine areas. Our project at Shirley Basin (the “Shirley Basin Project”) is located in Carbon County, Wyoming, approximately 40 miles south of Casper, Wyoming. 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 Shirley Basin Mine is to the east.

 

In addition to the two projects and related data, we acquired an extensive U.S. exploration and development database estimated to comprise hundreds of project descriptions in more than twenty states, including thousands of drill logs and geologic reports. Our geology team continues with its evaluation of this database, assessing opportunities for monetizing this additional asset. 

 

Under the terms of our acquisition of Pathfinder from AREVA in 2013, we were obligated to pay a five percent production royalty on production at the Shirley Basin Project under certain market conditions, if such conditions were triggered prior to June 30, 2016. That contingent royalty was capped to various triggers and could have been repurchased at our election. On June 30, 2016, the royalty lapsed and was terminated because the market conditions had not been triggered.

 

The tailings facility at the Shirley Basin site is one of the few remaining facilities in the United States that is licensed by the NRC to receive and dispose of byproduct waste material from other in situ uranium mines.  We

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assumed the operation of the byproduct disposal site and accepted deliveries throughout 2017 under several existing contracts.

 

Preliminary Economic Assessment for Shirley Basin Uranium Project

 

In 2014, we issued a Technical Report on Resources for the Shirley Basin Uranium Project Carbon County Wyoming (August 27, 2014). Subsequently, in January 2015, we issued a Preliminary Economic Assessment for the Shirley Basin Uranium Project Carbon County Wyoming, January 27, 2015 (the “Shirley Basin PEA”). The Shirley Basin PEA was prepared under the supervision of WWC Engineering. The current mineral resources at the Shirley Basin Project are estimated as follows:

 

Shirley Basin Uranium Project - Resource Summary

 

 

 

 

 

 

 

 

 

MEASURED

INDICATED

RESOURCE

AVG GRADE

SHORT TONS

POUNDS

AVG GRADE

SHORT TONS

POUNDS

AREA

% eU3O8

(X 1000)

(X 1000)

(X 1000)

(X 1000)

(X 1000)

FAB
TREND

0.280 

1,172 

6,574 

0.119 

456 

1,081 

AREA 5

0.243 

195 

947 

0.115 

93 

214 

TOTAL

0.275 

1,367 

7,521 

0.118 

549 

1,295 

 

 

 

MEASURED & INDICATED

0.230 

1,915 

8,816 

 

Notes:

1.

Sum of Measured and Indicated tons and pounds may not add to the reported total due to rounding.

2.

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

3.

Based on grade cutoff of 0.020 percent eU3O8 and a grade x thickness cutoff of 0.25 GT.

4.

Measured and Indicated Mineral Resources as defined in Section 1.2 of NI 43-101 (the CIM Definition Standards (CIM Council, 2014)).

5.

Resources are reported through July 2014.

6.

All reported resources occur below the historical, pre-mining static water table.

7.

Sandstone density is 16.0 cu. ft./ton.

 

Information shown in the table above differs from the disclosure requirements of the SEC. See Cautionary Note to U.S. 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 which were acquired with the acquisition of Pathfinder. 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 were able to be made entirely in Measured and Indicated categories of resources and there is no Inferred Resource included in the resource estimate for Shirley Basin. 

 

Shirley Basin History and Geology

 

The Shirley Basin property 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

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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 removal problems, so in 1961 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 United States. In 1968 market and production needs caused Utah Construction to move to open-pit mining and a conventional mill.  All production within the district since that time has been by open-pit methods.

 

Several companies operated uranium mines within the District, however three companies were dominant. Utah Construction/Pathfinder’s efforts were focused in the northern portions of the District, while Getty was largely in the central portions, and Kerr-McGee was in the southern portions. In 1960, Getty and Kerr-McGee joined together as Petrotomics Company to build a mill for joint processing of their production. The last mining in the District ended in 1992 when Pathfinder shut down production due to market conditions. Total production from Shirley Basin was 51.3 million pounds of uranium, of which 28.3 million pounds came from the Utah Construction/Pathfinder operations which we now own.

 

Resources which we are currently targeting for ISR production represent unmined extensions of mineral trends addressed in past open-pit mines. These extensions had been targeted for mining but were abandoned with shut-down of the mining operations in 1992.

 

The Shirley Basin mining 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). These units were tilted by Laramide tectonic forces and subsequently exposed to erosion, creating a “paleo-topographic” surface. In the northern half of the Basin 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 source of the Wind River sediments is granitic terrain within the nearby Laramie Range to the east and the Shirley Mountains to the southwest. 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.

 

The Wind River Formation is the host of all uranium mineralization mined within the Shirley Basin mining district. The lithology of the Wind River Formation is characterized by multiple thick, medium to coarse grained sandstones separated by thick claystone shale units. The individual sandstones and shales are typically 20 to 50 feet thick. Total thickness of the Wind River Formation ranges from approximately 400 to 500 feet. The two most dominant sandstones are named the Main and Lower Sands. The Lower Sand represents the basal sand unit of the Wind River Formation and in places lies directly above the underlying Cretaceous formations.

 

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.  The Main and Lower Sands are the primary hosts to mineralization which we are currently targeting for ISR development.  Studies we conducted in 2014, as well as previous studies by Pathfinder in the late 1990s, indicate that this mineralization is amenable to ISR extraction. The primary target is called the FAB Trend which represents the connecting mineral trend between two past-produced open-pits. A secondary target called Area 5 was also an ISR target for Pathfinder prior to shut-down of their mining operations in 1992.

 

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The Bootheel Project, LLC and The Bootheel Project – Shirley Basin, Wyoming

 

Canada Jetlines Ltd. (formerly, Jet Metal Corp.) has been the manager of The Bootheel Project, LLC venture since 2007.  Following a decision to not fund our portion of the budget for the venture’s budget year ending March 31, 2012, our ownership interest was reduced from 25% to approximately 19%. Since then, we have maintained our ownership interest by participating in the project’s budgets and programs, which have been limited to nominal land maintenance (payment of maintenance for unpatented mining claims and of state lease rentals) and general overhead (e.g., insurance). In April 2017, the Management Committee of the Bootheel Project determined to continue the ownership and maintenance on the Bootheel property for the fiscal year ending March 31, 2018, which is the fiscal year end of The Bootheel Project, LLC. No exploration or development activities are expected during 2018. Due to the continuing decline in the spot price of uranium combined with the reduction in minerals when the related lease was not renegotiated, we examined the valuation of the investment and determined that as a standalone investment, it had an insignificant value and was therefore fully impaired during 2016 resulting in a loss on investment of $1.1 million. 

 

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. Because of their greater financial and technical resources, competitive bidding processes involving such companies will be challenging; this competition extends to the further acquisition of properties and equipment, contractors and personnel required to explore and develop such properties. Additionally, these larger companies have greater resources to continue with their operations during periods of depressed market conditions.

 

Unlike other commodities, uranium does not trade on an open market.  Contracts are negotiated privately by buyers and sellers. Our existing long-term agreements are described in Item 1, Business and Properties, above and in Item 7, Management’s Discussion and Analysis, below.  Uranium prices are published by two of the leading industry-recognized independent market consultants, The Ux Consulting Company, 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 timeframe indicated:

 

 

 

 

 

 

 

 

 

December 31 of [year]

2012

2013

2014

2015

2016

2017

Spot price (US$)

$ 43.38

$ 34.50

$ 35.50

$ 34.23

$ 20.25

$ 23.75

LT price (US$)

$ 56.50

$ 50.00

$ 49.50

$ 44.00

$ 30.00

$ 31.00

 

 

 

 

 

 

 

 

 

 

End of [month]

31-Aug-17

30-Sep-17

31-Oct-17

30-Nov-17

31-Dec-17

31-Jan-18

28-Feb-18

Spot price (US$)

$ 20.13

$ 20.33

$ 20.08

$ 23.13

$ 23.75

$ 21.88

$ 21.63

LT price (US$)

$ 31.50

$ 30.50

$ 30.00

$ 31.00

$ 31.00

$ 30.00

$ 29.50

 

The Long-Term price as defined by Ux Consulting Company, LLC includes conditions for escalation (from current quarter) delivery timeframe (≥ 24 months), and quantity flexibility (up to ±10%) considerations.

 

Government Regulations

 

As set forth above, our exploration projects and operations at Lost Creek and our other projects in Wyoming 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 govern exploration, development, production, exports, various taxes, labor standards, occupational health and safety, waste

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disposal, 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 may impose substantial costs on us and will subject us to significant potential liabilities. 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.

 

Minerals exploration and development activities are subject to comprehensive regulation which may cause substantial delays or require capital outlays in excess of those anticipated, causing an adverse effect on our business operations. Minerals 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. Minerals extraction 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. As of this date, other than with respect to the posting of a performance bond and the costs associated with our permitting and licensing activities, we have not been required to spend material amounts on compliance with environmental regulations. However, we may be required to do so in the future and this may affect our ability to expand or maintain our operations.

 

Environmental Regulations

 

As set forth above, our mineral projects are the subject of extensive environmental regulation at federal, state and local levels.

 

Exploration, development and production activities are subject to certain environmental regulations which may prevent or delay the commencement or continuance of our operations. 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 and may prevent or delay the commencement or continuance of a given operation. Compliance with these laws and regulations has not had a material effect on our operations or financial condition to date. 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, legislation requires well and facility sites to be abandoned and reclaimed to the satisfaction of state and federal authorities.

 

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 United States 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.

 

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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 must have granted, upon request by the state, an aquifer exemption. The EPA may delay or decline to process the state's application if the EPA questions the state's jurisdiction over the mine site. The EPA commenced a rulemaking with its publication of 40 CFR Part 192 rules in early 2015. These proposed rules effectively seek to expand EPA jurisdiction in restoration of groundwater within an exempted aquifer, and propose to extend the time for monitoring such restoration and stabilization requirement for as much as thirty years following production. As proposed, the rules implicate RCRA, SDWA and Uranium Mill Tailings Radiation Control Act (UMTRCA) standards. The rulemaking is likely to take substantial time to complete and it is uncertain what the final rules will require. It is possible that additional requirements with attendant costs will result. 

 

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.

 

Most recently, in December 2017, the EPA declined to make final its rulemaking to amend current standards of financial responsibility under Section 108(b) of CERCLA, which requires that classes of facilities establish and maintain evidence of financial responsibility consistent with the degree and duration of risk associated with the production, transportation, treatment, storage, or disposal of hazardous substances. As it had been proposed, the rulemaking would have significantly increase the cost of bonding and reclaiming our mineral projects.

 

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.

 

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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.

 

Employees

 

At December 31, 2017, Ur-Energy USA employed 14 people in its Littleton, Colorado (8) and Casper, Wyoming (6) offices. Lost Creek ISR, LLC employed 36 people at the Lost Creek Project near Wamsutter, Wyoming.  None of our other subsidiaries had employees in 2017.  As reflected elsewhere in this report, subsequent to year end, we have implemented layoffs of nine employees (eight Lost Creek ISR and one Ur-Energy USA), and also chosen to not replace one position open due to an employee resignation. 

 

Corporate Offices

 

The registered office of Ur-Energy is located at 55 Metcalfe Street, Suite 1300, Ottawa, Ontario K1P 6L5.  Our United States corporate headquarters is located at 10758 West Centennial Road, Suite 200, Littleton, Colorado, 80127. We maintain a corporate and operations office at 5880 Enterprise Drive, Suite 200, Casper, Wyoming 82609. Lost Creek operational offices are located at 3424 Wamsutter / Crooks Gap Road, Wamsutter, Wyoming 82336.

 

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: 1-866-981-4588

Email: legaldept@ur-energy.com

 

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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. 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.sedar.com.  Our reports can be read and copied by the public at the SEC’s Public Reference Room at 100 F Street, N.E., Washington, D.C. 20549.

 

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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.

 

Risks Related to Our Business

 

Current inventories and largely unrestricted imports challenge the US domestic industry and our pending trade action may not achieve the desired results and may be costly to us.

 

Higher than normal inventories, sales of excess civilian and military inventories (including from the dismantling of nuclear weapons) by governments and industry participants, as well as the production levels and costs of production in countries such as Russia, Kazakhstan, and Uzbekistan have had a substantial impact on the domestic uranium production industry. If the higher inventories and the imports from Kazakhstan and other government subsidized production sites remain unchecked on a continuing basis, there could be a significant negative impact to the uranium market which could adversely impact the Company’s future profitability. We have jointly filed a petition for relief with the U.S. Department of Commerce under Section 232 of the Trade Expansion Act of 1962 from imports of uranium products that threaten U.S. national security. There is no assurance that the petition will result in any impact on the imports of uranium from low-cost state-sponsored production. Moreover, the petition may have unintended consequences that may affect our business relationships with industry and consumers of uranium. These consequences, together with the costs of pursuing the trade action, may have adverse impacts on us.

 

The uranium market is volatile and has limited customers.

 

The marketability of uranium and acceptance of uranium mining is subject to numerous factors beyond our control. The price of uranium may experience volatile and significant price movements over short periods of time. Factors affecting the market include demand for nuclear power; changes in public acceptance of nuclear power generation as a result of any future accidents or terrorism at nuclear facilities, including the continuing effects on the market due to the events following the earthquake and tsunami in Japan in March 2011; political and economic conditions in uranium mining, producing and consuming countries; costs and availability of financing of nuclear plants; reprocessing of spent fuel and the re-enrichment of depleted uranium tails or waste.

 

Our property interests and our projects are subject to volatility in the price of uranium.

 

The price of uranium is volatile. Changes in the price of uranium depend on numerous factors beyond our control including international, economic and political trends; changes in public acceptance of nuclear power generation as a result of any future accidents or terrorism at nuclear facilities, including the longer-term effects on the market due to the events following the earthquake and tsunami affecting the Fukushima Daiichi nuclear power station in Japan in 2011; changes in governmental regulations; expectations of inflation; currency exchange fluctuations; interest rates; global or regional consumption patterns; speculative activities and increased production due to new extraction developments and improved extraction and production methods. The effect of these factors on the price of uranium, and therefore on the economic viability of our properties cannot accurately be predicted.  Because most of our properties are in exploration and development stage and

29


 

Lost Creek commenced operations four years ago, it is not yet possible for us to control the impact of fluctuations in the price of uranium.

 

Mining operations involve a high degree of risk.

 

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 production activities commenced in the second half of 2013. Our operations at the Lost Creek site, which is a remote site in south-central Wyoming, and at other projects as they continue in development will be subject to all the hazards and risks normally encountered in the production of uranium by in situ methods of recovery, including unusual and unexpected geological formations, unanticipated metallurgical difficulties, water management including waste water disposal capacity, equipment malfunctions and parts unavailability, 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, any of which could result in damage to, or destruction of, mines and other producing facilities, damage to life or property, environmental damage and possible legal liability. 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.

 

We have entered into term sales contracts for a portion of our production, but may be unable to enter into new term sales contracts in the future on suitable terms and conditions.

 

Our term sales contracts, which have historically resulted in uranium sales at prices in excess of spot prices, have fixed delivery terms. Certain of our contracts have delivery terms that have expired with no future deliveries planned. We are contractually committed to sell 470,000 pounds in 2018, 540,000 pounds in 2019, 390,000 pounds in 2020 and 190,000 pounds in 2021. In each case, the sales price of these contracts is substantially in excess of current spot prices.  If market conditions do not improve, we do not expect to continue to execute sales agreements at such favorable prices in the future. The failure to enter into new term sales contracts on suitable terms, could adversely impact our operations and mining activity decisions, and resulting cash flows and income.

 

Our business is subject to extensive environmental and other regulations that may make exploring, mining or related activities expensive, and which 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 is evolving in a manner which will require stricter standards and enforcement, increased fines and penalties for non-compliance, more stringent environmental assessments of proposed projects and a heightened degree of responsibility for companies and their officers, directors and employees. In addition to the ESA decision made in 2015, to not list the greater sage-grouse as an endangered species, other rulemakings and proposed legislation are ongoing.  For example, the EPA continues with its rulemaking on changes to Part 192, which sets forth groundwater restoration and stabilization requirements for ISR uranium projects. Other EPA rulemakings relating to maintenance of tailings facilities and holding ponds, which may also have an impact on ISR projects, including Lost Creek are at various stages (e.g., UMTRCA, RCRA and SDWA restoration and stabilization requirements). The changes currently proposed to CERCLA regulations, which would significantly increase financial obligations and surety bonding, could also have a commensurate impact on ISR projects. These are not the only laws and regulations which are the subject of discussion and proposed more restrictive changes. Moreover, compliance with environmental quality requirements and reclamation laws imposed by federal, state and local governmental authorities may require significant capital outlays, 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

30


 

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 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 for liability may exist under federal or state remediation statutes.

 

The uranium mining industry is capital intensive, and we may be unable to raise necessary additional funding.

 

Additional funds likely may be required to fund working capital or to fund exploration and development activities at our properties including Lost Creek and the adjoining projects at the Lost Creek Property, as well as the development of our Shirley Basin project. Potential sources of future funds available to us, in addition to the sales proceeds from Lost Creek production, include the sale of additional equity capital, proceeds from the exercise of outstanding convertible equity instruments, borrowing of funds or other debt structure, project financing, or the sale of our interests in assets. There is no assurance that such funding will be available to us to continue development or future exploration. Furthermore, even if such financing is successfully completed, 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. In addition, any future equity financings may result in substantial dilution for our existing shareholders.

 

Our mineral resource estimates may not be reliable; there is risk and increased uncertainty to commencing and conducting production without established mineral reserves; and we need to develop additional resources to sustain ongoing operations.

 

Our properties do not contain any mineral reserves as defined under SEC Industry Guide 7. See “Cautionary Note to United States Investors Concerning Disclosure of Mineral Resources” above. Until mineral reserves or mineral resources are actually mined and processed, the quantity of mineral resources and grades must be considered as estimates only. We have established the existence of uranium resources for certain uranium projects, including the Lost Creek Property. We have not established proven or probable reserves, as defined by Canadian securities regulators or the SEC under Industry Guide 7, through the completion of a final or “bankable” feasibility study for any of its uranium projects, including the Lost Creek Property. Furthermore, we have no plans to establish proven or probable reserves for any of our uranium projects for which we plan on utilizing ISR mining, such as the Lost Creek Project or the Shirley Basin Project. As a result, and despite the fact that we commenced recovery of U3O8 at the Lost Creek Project in 2013, there is an 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 estimated mineral reserves or mineral resources will be realized. In general, estimates of mineral resources are based upon a number of factors and assumptions made as of the date on which the estimates were determined, including:

 

·

geological and engineering estimates that have inherent uncertainties and the assumed effects of regulation by governmental agencies;

·

the judgment of the geologists, engineers and other professionals preparing the estimate;

·

estimates of future uranium prices and operating costs;

·

the quality and quantity of available data;

·

the interpretation of that data; and

31


 

·

the accuracy of various mandated economic assumptions, all of which may vary considerably from actual results.

 

All estimates are, to some degree, uncertain. 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.

 

As well, because we are now in operation and are depleting our known resource at Lost Creek, we must continue to conduct exploration and develop additional mineral resources. While there remain large areas of our Lost Creek Property which require additional exploration, and we have identified mineral resources at our Shirley Basin Project, we will need to continue to explore other 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.

 

Restrictive covenants in agreements governing our indebtedness may restrict our ability to pursue our business strategies. If we are unable to service our indebtedness, we could lose the assets securing our indebtedness.

 

Our State Bond Loan, under which we originally received approximately $34 million in debt financing, includes restrictive covenants that, among other things, limit our ability to sell the assets securing our indebtedness (which include our Lost Creek Project and other related assets). Our ability to make scheduled payments and satisfy other covenants in the State Bond Loan depends on our financial condition and operating performance, which are subject to prevailing economic, competitive, legislative and regulatory conditions beyond our control. We may be unable to generate a level of cash flow from operating activities sufficient to permit us to pay the principal, interest and other fees on our indebtedness.

 

If we cannot make scheduled payments on our debt, we will be in default which, if not addressed or waived, could require accelerated repayment of our indebtedness and the enforcement by the lender against the assets securing our indebtedness. The secured collateral for the State Bond Loan includes the Lost Creek Project and other related assets. These are key assets on which our business is substantially dependent and as such, the enforcement against any one or all of these assets would have a material adverse effect on our operations and financial condition.

 

Our mining operations are subject to numerous environmental laws, regulations and permitting requirements and bonding requirements that can delay production and adversely affect operating and development costs.

 

Our business is subject to extensive federal, state, provincial and local laws governing prospecting and development, taxes, labor standards and occupational health, mine and radiation safety, toxic substances, environmental protection, endangered species protections, and 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, and particularly standards with respect to uranium recovery, to monitor the discharge of waste water and report the results of such monitoring to regulatory authorities, to reduce or eliminate certain effects on or into land, 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 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

32


 

of these laws and regulations have tended to become more stringent over time. Any change in such laws 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. Further, 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.

 

Many of our operations require licenses and permits from various governmental authorities. We believe we hold all necessary licenses and permits to carry on the activities which we are currently conducting or propose to conduct under applicable laws and regulations. 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 obtain all necessary licenses and permits that may be required to maintain our exploration and mining activities including constructing mines or milling facilities and commencing or continuing exploration or mining activities or operations at any of our properties. In addition, if we proceed to production on any other exploration property, 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 such conditions.

 

Lack of acceptance of nuclear energy and deregulation of the electrical utility industry could impede our business.

 

Our future prospects are tied directly to the electrical utility industry worldwide. Deregulation of the utility industry, particularly in the United States and Europe, is 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 the nuclear technology as a means of generating electricity.  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, a reaction worldwide called into question the public’s confidence in nuclear energy and technology, the effects of which are still apparent in many countries around the world.

 

The results of exploration and ultimate production are highly uncertain.

 

The exploration for, and development of, mineral deposits involves 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. Major expenses may be required to establish mineral resources or reserves, to develop metallurgical processes and to construct mining and processing facilities at a particular 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 a number of factors, some of which are the particular attributes of the deposit, such as size, grade and proximity to infrastructure, as well as uranium prices, which are highly cyclical, and government regulations, including regulations relating to prices, taxes, royalties, land tenure, land use, importing and exporting of uranium and environmental protection. 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.

 

33


 

The uranium industry is highly competitive and is competitive with other energy sources.

 

The international uranium industry is highly competitive. Our activities are directed toward the search for, evaluation, acquisition and development of uranium deposits into production operations. There is no certainty that the expenditures to be made by us will result in discoveries of commercial quantities of uranium deposits. There is aggressive competition within the mining industry for the discovery and acquisition of properties considered to have commercial potential. We will compete with other interests, many of which have greater financial resources than we have, for the opportunity to participate in promising projects. Significant capital investment is required to achieve commercial production from successful exploration and development efforts.

 

Nuclear energy competes with other sources of energy, including oil, natural gas, coal, hydro-electricity and renewable energy sources. These other energy sources are to some extent interchangeable with nuclear energy, particularly over the longer term. Lower prices of oil, natural gas, coal and hydro-electricity may result in lower demand for uranium concentrate and uranium conversion services. Furthermore, the 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, 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 and increase the regulation of the nuclear power industry.

 

Our property title 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 United States consist of leases to private mineral rights, leases covering state lands, unpatented mining claims and patented mining claims. Many of our mining properties in the United States 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 United States. We remain at risk that the mining claims may be forfeited either to the United States or to rival private claimants due to failure to comply with statutory requirements. We have taken or will take appropriate curative measures to ensure proper title to our properties where necessary and where possible.

 

Possible amendments to the General Mining Law could make it more difficult or impossible for us to execute our business plan.

 

Members of the United States Congress have repeatedly introduced bills which would supplant or alter the provisions of the United States Mining Law of 1872, as amended. Such bills have proposed, among other things, to (i) either eliminate or greatly limit the right to a mineral patent; (ii) significantly alter the laws and regulations relating to uranium mineral development and recovery from unpatented and patented mining claims; (iii) impose a federal royalty on production from unpatented mining claims; (iv) impose time limits on the effectiveness of plans of operation that may not coincide with mine life, (v) impose more stringent environmental compliance and reclamation requirements on activities on unpatented mining claims, (vi) establish a mechanism that would 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. general mining laws, and (vii)

34


 

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.

 

If enacted, such legislation could, among other effects, change the cost of holding unpatented mining claims and could significantly impact our ability to develop locatable mineral resources on our patented and unpatented mining claims. Although it is impossible to predict at this point what any legislated royalties might be, enactment could adversely affect the potential for development and the economics of existing operating mines. Passage of such legislation could adversely affect our financial performance.

 

Additionally, as noted in other risk factors, there are ongoing withdrawals of federal lands for the purposes of mineral location and development. While certain of these proposals have been withdrawn, and others are not final and, as yet, none directly affects the areas of Wyoming and Nevada in which we currently have land holdings, they could have an adverse effect on our financial performance if they are broadened in scope to directly affect the areas in which we have properties.

 

We do not have an established earnings record, and we have never paid dividends.

 

We do not have an established earnings record. We have not paid dividends on our Common Shares since incorporation and do not anticipate doing so in the foreseeable future. Payments of any dividends will be at the discretion of our Board after taking into account many factors, including our financial condition and current and anticipated cash needs.

 

We depend on the services of our management, key personnel, contractors and service providers.

 

Shareholders will be relying on the good faith, experience and judgment of our management and advisors in supervising and providing for the effective management of the business and our operations and in selecting and developing new investment and expansion opportunities. We may need to recruit additional qualified employees, contractors and service providers to supplement existing management and personnel, the timely availability of which cannot be assured, particularly in the current labor markets in which we recruit our employees and the somewhat remote locations for which employees are needed. As well, the skilled professionals with expertise in engineering and process aspects of in situ recovery, radiation safety and other facets of our business are currently in high demand, as there are relatively few such professionals with both expertise and experience. We will need to hire additional employees as we develop the Shirley Basin Project. We will continue to be dependent on a relatively small number of key persons, including 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 insurance coverage could be insufficient.

 

We currently carry insurance coverage for general liability, directors’ and officers’ liability and other matters.  We intend to carry insurance to protect against certain risks in such amounts as 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 in excess of insurance coverage or compliance with applicable laws and regulations may cause substantial delays and require significant capital outlays, adversely affecting our business and financial position. Additionally, we utilize a bonding surety program for our regulatory, reclamation and restoration obligations at Lost Creek Project and the Pathfinder

35


 

Mines sites. Availability of and terms for such surety arrangements may change in the future, resulting in adverse effects to our financial condition.

 

We are subject to risks associated with regulatory investigations or challenges, litigation 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 or other proceedings. Additionally, it is not unlikely that we may find ourselves involved directly or indirectly in legal proceedings, in the form of regulatory investigations, administrative proceedings or litigation, arising from challenges to regulatory actions as described elsewhere in this annual report. Such investigations, administrative proceedings and litigation related to regulatory matters may delay or halt exploration or development of our projects. The results of litigation or any other proceedings cannot be predicted with certainty. If we are unable to resolve any such disputes favorably, it could have a material adverse effect on our financial position, ability to operate, results of operations or our property development.

 

Acquisitions and integration may disrupt our business.

 

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 acquisitions would be accompanied by risks. For example, there may be a significant change in commodity prices after we have committed to complete the transaction and established the purchase price or share exchange ratio; a material ore body may prove to be below expectations; we may have difficulty integrating and assimilating the operations and personnel of any 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; the integration of the acquired business or assets may disrupt our ongoing business and relationships with employees, customers, suppliers and contractors; and the acquired business or assets may have unknown liabilities which may be significant. There can be no assurance that we would be successful in overcoming these risks or any other problems encountered in connection with such acquisitions.

 

We are dependent on information technology systems, which are subject to certain risks.

 

We depend upon information technology systems in a variety of ways throughout our operations.  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, could negatively impact our business and operations. To the extent that such invasion, 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.  Our systems, internal controls and insurance for protecting against such cyber security risks may be insufficient.  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.

 

36


 

U.S. Federal Income Tax Consequences to U.S. Shareholders under the Passive Foreign Investment Company Rules

 

Investors in the Common Shares of Ur-Energy 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, 2017 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 Common Shares of Ur-Energy 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:  (a) timely and accurate information as to our status as a PFIC and the PFIC status of any subsidiary in which Ur-Energy owns more than 50% of such subsidiary’s total aggregate voting power, and (b) for each year in which Ur-Energy determines that it is a PFIC, upon written request, a PFIC annual information statement with respect to Ur-Energy and with respect to each such subsidiary that we determine is 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.

 

Item 1B.  UNRESOLVED STAFF COMMENTS

 

None.

 

Item 3.  LEGAL PROCEEDINGS

 

None.

 

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”).

 

37


 

PART II

 

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.” The following table sets forth the price range per share and trading volume for the Common Shares:

 

 

 

 

 

 

 

NYSE

 

Common Shares

 

Volume

High

Low

Quarter Ending

 

US$

31-Mar-16

19,405,444

0.70

0.44

30-Jun-16

28,373,457

0.73

0.45

30-Sep-16

15,562,319

0.64

0.47

31-Dec-16

23,271,636

0.59

0.41

 

 

 

 

31-Mar-17

49,931,758

0.91

0.52

30-Jun-17

18,653,638

0.72

0.50

30-Sep-17

13,464,210

0.72

0.53

31-Dec-17

24,662,934

0.73

0.50

 

 

 

 

January 1, 2018 to February 28, 2018

15,167,873

0.78

0.64

 

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.” The following table sets forth the price range per share and trading volume for the Common Shares:

 

 

 

 

 

 

 

TSX

 

Common Shares

 

Volume

High

Low

Quarter Ending

 

CDN$

31-Mar-16

4,531,828

0.98

0.61

30-Jun-16

4,164,964

0.92

0.60

30-Sep-16

2,301,377

0.82

0.63

31-Dec-16

4,330,226

0.78

0.55

 

 

 

 

31-Mar-17

10,638,938

1.19

0.70

30-Jun-17

2,432,867

0.97

0.67

30-Sep-17

2,437,686

0.90

0.67

31-Dec-17

4,731,380

0.93

0.62

 

 

 

 

January 1, 2018 to February 28, 2018

2,326,642

0.98

0.80

 

 

38


 

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 March 1, 2018, 145,616,297 Common Shares are issued and outstanding and no preferred shares are issued and outstanding.  We estimate that we have approximately 8,000 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 directors in one or more series and the directors have 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.

 

Shareholder Rights Plan

 

Ur-Energy maintains a shareholder rights plan (the “Rights Plan”) designed to encourage the fair and equal treatment of shareholders in connection with any take-over bid for the Company's outstanding securities. The Rights Plan is intended to provide the Board with adequate time to assess a take-over bid, to consider alternatives to a take-over bid as a means of maximizing shareholder value, to allow competing bids to emerge, and to provide our shareholders with adequate time to properly assess a take-over bid without undue pressure. The Rights Plan was last reconfirmed by shareholders at Ur-Energy’s annual and special meeting of shareholders on May 28, 2015.

 

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 be dependent 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.

 

39


 

Securities Authorized for Issuance under Equity Compensation Plans

 

The following table sets forth certain summary information concerning our equity compensation plans as at December 31, 2017.  Directors, officers, employees, and consultants are eligible to participate in the Option Plan.  Directors and employees, including executive officers, are eligible to participate in the RSU Plan.

 

 

 

 

 

 

Number of Common Shares to be Issued Upon Exercise of Outstanding Options, Warrants and Rights (4)

Weighted Average Exercise Price of Outstanding Options, Warrants and Rights (2)

(C$)

Number of Common Shares Remaining for Future Issuance (Excluding Common Shares to be Issued Upon Exercise of Outstanding Options, Warrants and Rights) (3)

Equity compensation plans approved by securityholders (1)

16,479,920

$ 0.70

639,424

Equity compensation plans not approved by security-holders

 -

 -

 -

 

(1)

Our shareholders have approved both the Ur-Energy Inc. Amended and Restated Stock Option Plan 2005, as amended, and the Ur-Energy Inc. Amended Restricted Share Unit Plan.

(2)

The exercise price represents the weighted exercise price of the 9,459,401 outstanding stock options under the Ur‑Energy Inc. Amended and Restated Stock Option Plan 2005.

(3)

Represents 48,050 Common Shares remaining available for issuance under the Ur-Energy Inc. Amended and Restated Stock Option Plan 2005 and 591,374 Common Shares available under the Ur-Energy Amended Restricted Share Unit Plan.

(4)

The warrants included represent only those which form a portion of compensation for certain consultants and our commercial lender.

 

Recent Sales of Unregistered Securities

 

On August 19, 2014, we filed a universal shelf registration statement on Form S-3 in order that we may offer and sell, from time to time, in one or more offerings, at prices and terms to be determined, up to $100 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 our senior and subordinated debt securities.  The registration statement became effective September 12, 2014. The 12,921,000 Common Shares offered in the February 2016 financing were sold for $0.50 per share raising $5.7 million (net of issue costs of $0.8 million) under the shelf registration statement. 

 

On May 27, 2016, we entered into an At Market Issuance Sales Agreement with MLV & Co. LLC and FBR Capital Markets & Co. under which 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 distribution agents for aggregate sales proceeds of up to $10,000,000. During 2017, we sold 1,536,169 Common Shares under the sales agreement at an average price of $0.76 per share for gross proceeds of $1.2 million. After deducting transaction fees and commissions and all other costs we received net proceeds of $1.1 million.

 

During the fiscal years ended December 31, 2017 and 2016, we did not have any sales of securities in transactions that were not registered under the Securities Act.

40


 

Issuer Purchases of Equity Securities

 

The Company did not purchase its own equity securities during the fiscal year ended December 31, 2017.

 

Performance Graph

 

The following information in this Item 5 of this Annual Report on Form 10-K is not deemed to be “soliciting material” or to be “filed” with the SEC or subject to the liabilities of Section 8 of the Exchange Act, and will not be deemed to be incorporated by reference into any filing under the Securities Act or the Exchange Act, except to the extent we specifically incorporate it by reference into such a filing.

 

The following graph illustrates the period from December 31, 2012 to December 31, 2017 and reflects the cumulative shareholder return of an investment in our Common Shares compared to the cumulative return of an investment in (a) the Russell 3000 Index, (b) the NYSE American Composite Index, and (c) the average of a peer group consisting of Denison Mines Corp., Uranium Energy Corp., Energy Fuels, Inc. and Westwater Resources, Inc. since December 31, 2012, assuming that $100 was invested and, where applicable, includes the reinvestment of dividends.

 

Picture 3

 

41


 

 

 

 

 

 

 

 

 

 

2012

2013

2014

2015

2016

2017

Ur-Energy Inc.

100

168

111

92

74

92

NYSE American Index

100

103

104

91

98

113

Russell 3000

100

131

145

143

157

187

Peer Average

100

84

70

36

38

43

 

 

 

 

Item 6.  SELECTED FINANCIAL DATA

 

The selected financial data set forth below are derived from our audited consolidated financial statements for the years ended December 31, 2017, 2016, 2015, 2014 and 2013, and should be read in conjunction with those financial statements and the notes thereto. The consolidated financial statements have been prepared in accordance with United States generally accepted accounting principles (“US GAAP”). Reference should also be made to “Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations.”

 

Summary of Financial Condition

 

(Amounts in thousands of U.S. Dollars except per share data) 

 

 

 

 

 

 

 

 

 

As of December 31

 

2017

2016

2015

2014

2013

Working capital (deficiency)

1,283

(1,706)

(7,510)

(2,645)

(242)

Current assets

9,168

6,506

5,713

9,346

10,432

Total assets

88,364

89,940

95,757

104,451

105,336

Current liabilities

7,885

8,212

13,223

11,991

10,674

Long-term liabilities

41,698

45,496

50,033

60,359

55,998

Shareholders' equity

38,781

36,232

32,501

32,101

38,664

 

 

 

 

 

 

 

 

 

 

Year ended December 31

 

2017

2016

2015

2014

2013

Revenue

38,368

27,305

41,877

29,349

7,616

Net income (loss) for the year

76

(3,010)

(795)

(8,749)

(30,353)

 

 

 

 

 

 

Income (loss) per common share:

    Basic

0.00

(0.02)

(0.01)

(0.07)

(0.25)

   Diluted

0.00

(0.02)

(0.01)

(0.07)

(0.25)

 

 

 

 

 

 

Cash dividends per common share

Nil

Nil

Nil

Nil

Nil

 

No dividends were paid during these five years.

 

42


 

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 Update and Trends

 

The uranium industry continues to be characterized by persistently low pricing. In 2017, several uranium miners, including Lost Creek, implemented reductions in planned construction and development as well as lower rates of production operations. Both early and late in the year, announcements of such reductions were made by leading producers, including Cameco’s November 2017 plan to shut-in production at McArthur River, the world’s largest uranium mine for at least ten months in 2018. As discussed elsewhere in this report, we determined to proceed with a moderated level of development in Lost Creek’s second mine unit to initiate operations in only the first three header houses, while controlling annual production rates at a modest target of 250,000 to 300,000 pounds.  Production at Lost Creek in 2017 totaled 265,391 pounds captured in the plant.  While U.S. miners lowered production rates, foreign imports continued to dominate the U.S. market in 2017, with U.S. miners accounting for less than five percent of domestic uranium needs.

 

In response to the challenges of the market conditions, primary among them foreign imports to the U.S. emanating from state-sponsored producers in Russia, Kazakhstan and Uzbekistan, in January 2018, Ur-Energy USA and Energy Fuels Resources (USA) Inc. (Energy Fuels) initiated a trade action with the U.S. Department of Commerce pursuant to Section 232 of the Trade Expansion Act. We chose this statutory framework for relief because we recognized that the current imbalance in the U.S. uranium market has created a very real threat to our national security. 

 

On January 16, 2018, we announced the filing of a Petition for Relief with the U.S. Department of Commerce under Section 232 of the Trade Expansion Act of 1962 (as amended) From Imports of Uranium Products that Threaten U.S. National Security. The Petition, which was filed jointly with Energy Fuels, describes how uranium and nuclear fuel from state-owned and state-subsidized enterprises in Russia, Kazakhstan, Uzbekistan, and China represent a threat to U.S. national security. The Petition seeks a remedy which will set a quota to limit imports of uranium into the U.S., effectively reserving 25% of the U.S. nuclear market for U.S. uranium production. Additionally, the Petition suggests implementation of a requirement for U.S. federal utilities and agencies to buy U.S. uranium in accordance with the Administration's Buy American Policy. There can be no certainty of the outcome of the Department of Commerce investigation or the recommendation of the Secretary of Commerce, and therefore the outcome of this process and its effects on the U.S. uranium market is uncertain

 

2017 Developments

 

Lost Creek Property – Great Divide Basin, Wyoming

 

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

43


 

holding ponds, warehouse building, and drill shed building. In August 2013, the Company was given operational approval by the NRC and commenced production operation activities.

Production operations in MU1 within the HJ Horizon began on August 2, 2013 and, through December 31, 2017, 2,334,611 pounds of uranium have been captured from this mine unit, and an additional 38,875 pounds recovered from the first header house in MU2, which came online in August 2017.

All of the original planned wells and 13 header houses (“HHs”) in MU1 as well as one header house and the related wells in MU2 have been completed and were in operation at year end 2017.  In January 2018, the second header house in MU2 came online; the third of three MU2 houses developed in 2017 will come online in Q1 2018. Additional work in MU2 had been completed earlier, allowing for submittal of the appropriate operating permits. The main trunkline which has been installed services the first five header houses, and the entirety of MU2 has been fenced. All of these activities will allow for a quick turn-around to production once market fundamentals change. 

After more than four years of operations, MU1 still produced 226,516 pounds during 2017 with a yearly average head grade of 25 ppm. Together with the first of the MU2 production coming online in Q3, the annual average head grade for Lost Creek was 28 ppm. The lower head grade during this period of operation, as well as varying month-to-month grades, is a typical result as a mine matures and older operating patterns remain in the flow regime.

During 2017, the Company sold 780,000 pounds under contract at an average price of $49.09. From production, Lost Creek sold a total of 261,000 pounds U3O8  during 2017 at an average price of $48.81 per pound. The balance was purchased for resale, at an average price of $21.35 per pound. During 2017, 265,391 pounds of U3O8 were captured within the Lost Creek plant; 254,012 pounds U3O8  were packaged in drums; and 257,213 pounds U3O8  of drummed inventory were shipped from the Lost Creek processing plant to the converter. At December 31, 2017, inventory at the conversion facility was approximately 94,077 pounds U3O8.

 

Lost Creek Regulatory Proceedings

 

After receiving notice of final operational clearance from the NRC, we commenced production activities at Lost Creek in August 2013. Subsequent to those final approvals, we have made necessary additional filings for approvals of ongoing operations at Lost Creek (e.g., wellfield development; authorizations related to the new deep disposal well; permits and authority for new Class V wells).  In September 2014, we filed applications for amendment of all Lost Creek permits and licenses to include recovery from the KM horizon and LC East operations. In 2015, the BLM issued a notice of intent to complete an environmental impact statement for the application. The NRC is participating in this review as a cooperating agency. A permit amendment requesting approval to mine at the LC East Project and within the KM Horizon at the Lost Creek Project was also submitted to the WDEQ. Approval will include an aquifer exemption. At this time, all of those applications continue through the regulatory process, except we have recently withdrawn the application insofar as it relates to two of the eleven projected mine units – those for the KM Horizon at Lost Creek. This change should not delay the completion of the permitting process with respect to the LC East Project (nine mine units total).  It is anticipated that permits and authorizations will be completed in 2018.

 

By the end of 2016, all general regulatory authorizations for Underground Injection Control (UIC) Class V wells were completed for Lost Creek. Following pre-operational analyses and final testing, final operational approvals were received from regulators in December 2016. These relatively shallow Class V wells, which are the first of their kind at an ISR uranium facility, allow for the onsite recirculation of up to 200 gpm of fresh permeate (i.e., clean water) from operations. The wells and the reverse osmosis (“RO”) system were brought online in early 2017 and were operational for much of the year. Site operators use the RO circuits, which were installed during initial construction of the plant, to process waste water into brine and permeate streams. The

44


 

brine stream will continue to be disposed of in the UIC Class I deep wells while the clean, permeate stream will be injected into the UIC Class V wells. The system ultimately reduces injection requirements in our Class I deep disposal wells and extends the life of those valuable assets.

 

Shirley Basin Project

 

Baseline studies necessary for the permitting and licensing of the project commenced in 2014 and were completed in 2015. Subsequently, in December 2015, our application for a permit to mine was submitted to the WDEQ. While the Shirley Basin PEA contemplates that the Lost Creek processing facility may be utilized for the drying and packaging of uranium from Shirley Basin, which would mean we would only anticipate the need only for a satellite plant, the Shirley Basin permit application contemplates the construction of a full processing facility, providing greater construction and operating flexibility as may be dictated by market conditions. 

 

In addition to the WDEQ application for permit to mine, work is well underway on other applications for all necessary authorizations to mine at Shirley Basin. We have worked cooperatively with others in our industry to assist with the development of the Wyoming “agreement state” program, by which the NRC will delegate its authority for source material licensure and other radiation safety issues to the WDEQ. We understand that the development of the Wyoming URP remains on schedule for full implementation and transition likely occurring in 2018. Based upon that timing, we currently anticipate submitting our application for a source material license for Shirley Basin to the State URP in 2018.

 

The Bootheel Project, LLC

 

In April 2017, the Management Committee of the Bootheel Project determined to continue the ownership and maintenance on the Bootheel property for the fiscal year ending March 31, 2018, which is the fiscal year end of The Bootheel Project, LLC. No additional exploration or development activities are expected at this time for 2018. Due to the continuing decline in the spot price of uranium combined with the reduction in minerals when the related lease was not renegotiated, the Company examined the valuation of the investment and determined that as a standalone investment, it had an insignificant value and was therefore fully impaired during 2016 resulting in a loss on investment of $1.1 million.

 

Excel Gold Project

 

In January 2018, we announced the acquisition of a gold exploration project in west-central Nevada, comprising 102 federal lode mining claims (approximately 2,100 acres) currently. The Excel Project is located within the Excelsior Mountains, in proximity to the Camp Douglas and Candelaria Mining Districts. We became aware of the mineral potential of this project area from exploration data contained within the large geologic database acquired as a part of our 2013 purchase of Pathfinder. Compiled over several decades of exploration work by major mining companies, the database contains valuable information on hundreds of mineral deposits and historical exploration and development programs in more than 20 states in the U.S.  In this instance, we identified an exploration program in the area of the Excel Project which encountered high-grade gold and silver assays from trenching activities. Company geologists conducted geologic literature research and field examinations, resulting in the initiation of land acquisition activities in March 2017. Once a land position was obtained, rock sampling and geochemical soil sampling programs were conducted. We continue to review and analyze the assay results from the sampling programs, and are considering all alternatives to advance this new exploration project, including drilling the project, identifying a venture partner, or through a sale process.

 

Corporate Transactions and Financing Developments

 

45


 

At Market Financing

 

In May 2016, we entered into an At Market Issuance Sales Agreement with MLV & Co. LLC and FBR Capital Markets & Co. under which 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 distribution agents for aggregate sales proceeds of up to $10,000,000. During 2017, we sold 1,536,169 Common Shares under the sales agreement. In conjunction with filing for a renewed shelf registration statement in 2017, the At Market Issuance Sales Agreement was amended and remains in place. See discussion below under Material Changes in Financial Condition, Liquidity and Capital Resources.

 

Off Take Sales Agreements

 

As of December 31, 2017, we have multiple off take sales agreements with various U.S. utilities. These agreements were completed between 2012 and 2015, and now provide for deliveries between 2018 and 2021 as follows: 

 

 

 

SUMMARY OF OFF TAKE SALES AGREEMENTS

Production Year

Total Pounds Uranium Concentrates Contractually Committed

2018

470,000 pounds

2019

540,000 pounds

2020

390,000 pounds

2021

190,000 pounds

 

Corporate Organization and Management

 

In September 2017, Kathy E. Walker was appointed to our Board. The appointment expanded the size of the Board to seven. Ms. Walker is the president and chief executive officer of Elm Street Resources Inc., an energy marketing company based in Paintsville, Kentucky. She brings more than 30 years’ experience in various energy-related business endeavors to our Board. 

 

In January 2018, one of our founding directors, Paul Macdonell provided notice of his retirement from our Board after more than 13 years of service. Originally projected to become effective March 1, 2018, Mr. Macdonell has agreed to extend the effective date of his retirement.

 

In March 2017, reductions in workforce were implemented due to continuing depressed uranium market conditions. Eight employees were laid off, and several other employees were asked to change job responsibilities or carry additional responsibilities. Operations at Lost Creek proceeded uninterrupted. A further reduction in force was implemented in February 2018, in which nine employees were laid off, following our Board’s decision to defer any further development at Lost Creek while the uranium market remains at its current depressed levels. Because of the deferral of construction and development, the focus of the layoffs was on positions in the construction and development teams, with additional positions eliminated in departments where the absence of field work will affect workload. Additionally, several employees were asked to change job responsibilities and/or team assignments. We anticipate that Lost Creek operations, at the controlled levels of production will continue uninterrupted.

 

 

46


 

2017 Results of Operations

 

U3O8 Production Costs

 

During 2017, 265,391 pounds of U3O8 were captured within the Lost Creek plant. A total of 254,012 pounds were packaged in drums and 257,213 pounds of the drummed inventory were shipped to the conversion facility where 261,000 produced pounds were sold to utility customers. The cash cost per pound and non-cash cost per pound for produced uranium presented in the following Production Costs and U3O8 Sales and Cost of Sales tables are non-US GAAP measures. These measures do not have a standardized meaning 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. Please see the tables, below, for reconciliations of these measures to the US GAAP compliant financial measures.  Production figures for the Lost Creek Project are as follows:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Production and Production Costs

    

Unit

    

2017 Q4

    

2017 Q3

    

2017 Q2

    

2017 Q1

    

2017 YTD

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Pounds captured

 

lb

 

 

67,982

 

 

52,812

 

 

65,257

 

 

79,340

 

 

265,391

 

Ad valorem and severance tax

 

$000

 

$

160

 

$

119

 

$

227

 

$

241

 

$

747

 

Wellfield cash cost (1)

 

$000

 

$

686

 

$

743

 

$

599

 

$

889

 

$

2,917

 

Wellfield non-cash cost (2)

 

$000

 

$

574

 

$

730

 

$

780

 

$

776

 

$

2,860

 

Ad valorem and severance tax per pound captured

 

$/lb

 

$

2.35

 

$

2.25

 

$

3.48

 

$

3.04

 

$

2.81

 

Cash cost per pound captured

 

$/lb

 

$

10.09

 

$

14.07

 

$

9.18

 

$

11.20

 

$

10.99

 

Non-cash cost per pound captured

 

$/lb

 

$

8.44

 

$

13.82

 

$

11.95

 

$

9.78

 

$

10.78

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Pounds drummed

 

lb

 

 

60,461

 

 

48,336

 

 

70,833

 

 

74,382

 

 

254,012

 

Plant cash cost (3)

 

$000

 

$

1,210

 

$

1,120

 

$

1,267

 

$

1,488

 

$

5,085

 

Plant non-cash cost (2)

 

$000

 

$

493

 

$

494

 

$

491

 

$

491

 

$

1,969

 

Cash cost per pound drummed

 

$/lb

 

$

20.01

 

$

23.17

 

$

17.93

 

$

20.00

 

$

20.02

 

Non-cash cost per pound drummed

 

$/lb

 

$

8.15

 

$

10.20

 

$

6.93

 

$

6.61

 

$

7.75

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Pounds shipped to conversion facility

 

lb

 

 

73,367

 

 

36,797

 

 

74,406

 

 

72,643

 

 

257,213

 

Distribution cash cost (4)

 

$000

 

$

48

 

$

24

 

$

26

 

$

47

 

$

145

 

Cash cost per pound shipped

 

$/lb

 

$

0.65

 

$

0.65

 

$

0.35

 

$

0.65

 

$

0.56

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Pounds purchased

 

lb

 

 

 -

 

 

109,000

 

 

210,000

 

 

200,000

 

 

519,000

 

Purchase costs

 

$000

 

$

 -

 

$

2,196

 

$

4,870

 

$

4,015

 

$

11,081

 

Cash cost per pound purchased

 

$/lb

 

$

 -

 

$

20.15

 

$

23.19

 

$

20.08

 

$

21.35

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Notes:

1.

Wellfield cash costs include all wellfield operating costs. Wellfield construction and development costs, which include wellfield drilling, header houses, pipelines, power lines, roads, fences and disposal wells, are treated as development expense and are not included in wellfield operating costs.

2.

Non-cash costs include the amortization of the investment in the mineral property acquisition costs and the depreciation of plant equipment, and the depreciation of their related asset retirement obligation costs. The expenses are calculated on a straight line basis so the expenses are typically constant for each quarter. The cost per pound from these costs will therefore typically vary based on production levels only.

3.

Plant cash costs include all plant operating costs and site overhead costs.

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4.

Distribution cash costs include all shipping costs and costs charged by the conversion facility for weighing, sampling, assaying and storing the U3O8 prior to sale.

 

In total, wellfield, plant and distribution cash costs were very consistent quarter on quarter during 2017. The respective cash costs per pound increased overall during the year primarily driven by decreasing levels of production. 

 

Ad valorem and severance taxes fluctuate based on pounds extracted and the related sales value of those pounds.  

 

Wellfield cash costs in 2017 Q1 were somewhat elevated due to some non-recurring expenses and the annual labor bonus in Q1. They were again elevated in Q3 due to increased activity related to the development of MU2 but declined in Q4 as most of the drilling for the three planned header houses in MU2 was complete in Q3.  The average cash cost per pound captured increased to $10.09 in 2017 Q4 and averaged $10.99 for the year, as compared to $6.66 in 2016. The increase was due to lower average production levels during the year. As previously discussed, production levels were deliberately maintained at levels sufficient to satisfy our expected contract sales in light of the depressed uranium market. Wellfield non-cash costs were relatively fixed until Q4 when a portion of the capitalized ARO costs became fully depreciated. The resulting non-cash cost per pound captured was $8.44 in Q4 and averaged $10.78 for the year, as compared to $5.70 in 2016. Again, the increase for the year was due to lower production levels.

 

Plant cash costs generally decreased during the year with the higher costs in 2017 Q1 being driven by the annual labor bonus. Despite the lower cash costs, the resulting cash cost per pound drummed increased to $20.01 in 2017 Q4 as a result of lower production and averaged $20.02 for the year, as compared to $10.87 in 2016.  Plant non-cash costs did not change during the year. The non-cash cost per pound drummed increased to $8.15 in 2017 Q4 and averaged $7.75 for the year, as compared to $3.53 in 2016. The increase was again due to lower production rates.

 

With the exception of 2017 Q4, distribution costs decreased during the year, as did pounds shipped. The resulting cash cost per pound shipped in 2017 Q4 increased to $0.65 and averaged $0.56 per pound for the year, as compared to $0.63 in 2016.  Distribution costs are closely tied to volume, and the resulting cash cost per pound did not change significantly.

 

48


 

U3O8 Sales and Cost of Sales

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Sales and cost of sales

   

Unit