Energy Fuels Inc.
Annual Report 2017

Plain-text annual report

UNITED STATES SECURITIES AND EXCHANGE COMMISSION Washington, D.C. 20549 FORM 10-K [X] ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 For the fiscal year ended December 31, 2017 OR [ ] TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 For the transition period from to Commission file number: 001-36204 ENERGY FUELS INC. (Exact Name of Registrant as Specified in its Charter) Ontario, Canada 98-1067994 (State of other jurisdiction of incorporation or (I.R.S. Employer Identification No.) organization) 225 Union Blvd., Suite 600 Lakewood, Colorado (Address of Principal Executive Offices) 80228 (Zip Code) (303) 389-4130 (Registrant’s Telephone Number, including Area Code) 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, Toronto Stock Exchange 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 [X] Indicate by check mark if the registrant is not required to file reports pursuant to Section 13 or Section 15(d) of the Act. Yes [ ] No [X] Indicate by checkmark whether the registrant (1) 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 [X] 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 (§ 229.405 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 [X] No [ ] Indicate by checkmark if disclosure of delinquent filers pursuant to Item 405 of Regulation S-K is not contained herein, and will not be contained, to the best of the registrant’s knowledge, in definitive proxy or information statements incorporated by reference in Part III of this Form 10-K or any amendment to the Form 10-K. [ ] Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, or a non-accelerated filer. See the definitions of “large accelerated filer”, “accelerated filer”, “smaller reporting company”, and "emerging growth company" in Rule 12b-2 of the Exchange Act (Check one): Large Accelerated Filer [ ] Accelerated Filer [X] Non-Accelerated Filer [ ] Smaller Reporting Company [ ] Emerging Growth Company [X] Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Act). Yes [ ] No [X] State the aggregate market value of the voting and non-voting common equity held by non-affiliates computed by reference to the price at which the common equity was last sold, or the average bid and asked price of such common equity, as of the last business day of the registrant’s most recently completed second fiscal quarter: $101,781,932 The number of common shares of the Registrant outstanding as of March 8, 2018 was 75,676,406. 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. SUBPARTS PART I PART II ENERGY FUELS INC. FORM 10-K For the Year Ended December 31, 2017 TABLE OF CONTENTS ITEM I: CAUTIONARY STATEMENT REGARDING FORWARD-LOOKING STATEMENTS 3 ITEM II: CAUTIONARY NOTE TO UNITED STATES INVESTORS CONCERNING DISCLOSURE OF MINERAL RESOURCES ITEM III: GLOSSARY OF TECHNICAL TERMS ITEM 1. DESCRIPTION OF BUSINESS ITEM 1A. RISK FACTORS ITEM 1B. UNRESOLVED STAFF COMMENTS ITEM 2. DESCRIPTION OF PROPERTIES ITEM 2A. OVERVIEW ITEM 2B. SUMMARY OF MINERAL RESERVES AND RESOURCES ITEM 2C. THE NICHOLS RANCH PROJECT ITEM 2D. THE ALTA MESA PROJECT ITEM 2E. THE WHITE MESA MILL ITEM 2F. THE CANYON MINE ITEM 2G. THE ROCA HONDA PROJECT ITEM 2H. THE SHEEP MOUNTAIN PROJECT ITEM 2I. THE HENRY MOUNTAINS COMPLEX ITEM 2J. THE LA SAL PROJECT ITEM 2K. THE DANEROS PROJECT ITEM 2L. NON-MATERIAL MINERAL PROPERTIES ITEM 3. LEGAL PROCEEDINGS ITEM 4. MINE SAFETY DISCLOSURE ITEM 5. MARKET FOR THE REGISTRANT’S COMMON EQUITY, RELATED STOCKHOLDER MATTERS AND ISSUER PURCHASES OF EQUITY SECURITIES ITEM 6. SELECTED FINANCIAL DATA ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS ITEM 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA ITEM 8A. REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM ITEM 8B. CONSOLIDATED STATEMENTS OF OPERATIONS AND COMPREHENSIVE LOSS ITEM 8C. CONSOLIDATED BALANCE SHEETS ITEM 8D. CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY ITEM 8E. CONSOLIDATED STATEMENTS OF CASH FLOWS ITEM 8F. NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS FOR THE THREE YEARS ENDED DECEMBER 31, 2017 ITEM 8F(i). THE COMPANY AND DESCRIPTION OF BUSINESS ITEM 8F(ii). BASIS OF PRESENTATION ITEM 8F(iii). SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES ITEM 8F(iv). ACQUISITION OF THE ALTA MESA ISR PROJECT 1 6 8 11 24 36 37 38 40 44 54 62 67 74 80 87 93 100 106 113 114 115 118 120 131 133 134 136 137 138 140 142 142 142 142 148 ITEM 8F(v). ACQUISITION OF URANERZ ENERGY CORPORATION ITEM 8F(vi). RECEIVABLES ITEM 8F(vii). INVENTORIES ITEM 8F(viii). INTANGIBLE ASSETS ITEM 8F(ix). PLANT AND EQUIPMENT AND MINERAL PROPERTIES ITEM 8F(x). IMPAIRMENTS ITEM 8F(xi). ASSET RETIREMENT OBLIGATIONS AND RESTRICTED CASH ITEM 8F(xii). LOANS AND BORROWINGS ITEM 8F(xiii). CAPITAL STOCK ITEM 8F(xiv). BASIC AND DILUTED LOSS PER COMMON SHARE ITEM 8F(xv). SHARE-BASED PAYMENTS ITEM 8F(xvi). INCOME TAXES ITEM 8F(xvii). SUPPLEMENTAL FINANCIAL INFORMATION ITEM 8F(xviii). COMMITMENTS AND CONTINGENCIES ITEM 8F(xix). SEGMENT INFORMATION ITEM 8F(xx). UNAUDITED SUPPLEMENTARY QUARTERLY INFORMATION ITEM 8F(xxi). FAIR VALUE ACCOUNTING ITEM 8F(xxii). RELATED PARTY TRANSACTIONS ITEM 8F(xxiii). SUBSEQUENT EVENTS ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND FINANCIAL DISCLOSURE ITEM 9A. CONTROLS AND PROCEDURES ITEM 9B. OTHER INFORMATION PART III PART IV SIGNATURES ITEM 10. DIRECTORS, EXECUTIVE OFFICERS AND CORPORATE GOVERNANCE ITEM 11. EXECUTIVE COMPENSATION ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT AND RELATED STOCKHOLDER MATTERS ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS AND DIRECTOR INDEPENDENCE ITEM 14. PRINCIPAL ACCOUNTANT FEES AND SERVICES ITEM 15. EXHIBITS AND FINANCIAL STATEMENT SCHEDULES ITEM 16. FORM 10-K SUMMARY 149 150 150 150 151 151 152 153 154 156 156 160 162 163 164 165 165 168 168 168 169 170 171 171 171 171 171 171 176 177 2 CAUTIONARY STATEMENT REGARDING FORWARD-LOOKING STATEMENTS This Annual Report and the exhibits attached hereto (the “Annual Report”) contain “forward-looking statements” within the meaning of applicable US and Canadian securities laws. Such forward-looking statements concern Energy Fuels Inc.’s (the “Company” or “Energy Fuels”) anticipated results and progress of the Company’s operations in future periods, planned exploration, and, if warranted, development of its properties, plans related to its business, and other matters that may occur in the future. These statements relate to analyses and other information that are based on forecasts of future results, estimates of amounts not yet determinable and assumptions of management. Any statements that express or involve discussions with respect to predictions, expectations, beliefs, plans, projections, objectives, schedules, assumptions, future events, or performance (often, but not always, using words or phrases such as “expects” or “does not expect,” “is expected,” “anticipates” or “does not anticipate,” “plans,” “estimates” or “intends,” or stating that certain actions, events or results “may,” “could,” “would,” “might,” or “will” be taken, occur or be achieved) are not statements of historical fact and may be forward-looking statements. Forward-looking statements are based on the opinions and estimates of management as of the date such statements are made. Energy Fuels believes that the expectations reflected in these forward-looking statements are reasonable, but no assurance can be given that these expectations will prove to be correct, and such forward-looking statements included in, or incorporated by reference into, this Annual Report should not be unduly relied upon. This information speaks only as of the date of this Annual Report. Readers are cautioned that it would be unreasonable to rely on any such forward-looking statements and information as creating any legal rights, and that the statements and information are not guarantees and may involve known and unknown risks and uncertainties, and that actual results are likely to differ (and may differ materially) and objectives and strategies may differ or change from those expressed or implied in the forward-looking statements or information as a result of various factors. Such risks and uncertainties include risks generally encountered in the exploration, development, operation, and closure of mineral properties and processing facilities. Forward-looking statements are subject to a variety of known and unknown risks, uncertainties and other factors which could cause actual events or results to differ from those expressed or implied by the forward-looking statements, including, without limitation: • • • • • • • • • • • • • • • risks associated with mineral reserve and resource estimates, including the risk of errors in assumptions or methodologies; risks associated with estimating mineral extraction and recovery, forecasting future price levels necessary to support mineral extraction and recovery, and the Company’s ability to increase mineral extraction and recovery in response to any increases in commodity prices or other market conditions; uncertainties and liabilities inherent to conventional mineral extraction and recovery and/or in-situ uranium recovery operations; geological, technical and processing problems, including unanticipated metallurgical difficulties, less than expected recoveries, ground control problems, process upsets, and equipment malfunctions; risks associated with the depletion of existing mineral resources through mining or extraction, without replacement with comparable resources; risks associated with identifying and obtaining adequate quantities of alternate feed materials and other feed sources required for operation of the White Mesa Mill; risks associated with labor costs, labor disturbances, and unavailability of skilled labor; risks associated with the availability and/or fluctuations in the costs of raw materials and consumables used in the Company’s production processes; risks associated with environmental compliance and permitting, including those created by changes in environmental legislation and regulation, and delays in obtaining permits and licenses that could impact expected mineral extraction and recovery levels and costs; actions taken by regulatory authorities with respect to mineral extraction and recovery activities; risks associated with the Company’s dependence on third parties in the provision of transportation and other critical services; risks associated with the ability of the Company to extend or renew land tenure, including mineral leases and surface use agreements, on favorable terms or at all; risks associated with the ability of the Company to negotiate access rights on certain properties on favorable terms or at all; the adequacy of the Company's insurance coverage; uncertainty as to reclamation and decommissioning liabilities; 3 • • • • • • • • • • • • • • • • • • • • • • • • • • • • • • • • • • the ability of the Company’s bonding companies to require increases in the collateral required to secure reclamation obligations; the potential for, and outcome of, litigation and other legal proceedings, including potential injunctions pending the outcome of such litigation and proceedings; the ability of the Company to meet its obligations to its creditors; risks associated with paying off indebtedness at its maturity; risks associated with the Company’s relationships with its business and joint venture partners; failure to obtain industry partner, government, and other third party consents and approvals, when required; competition for, among other things, capital, mineral properties, and skilled personnel; failure to complete proposed acquisitions and incorrect assessments of the value of completed acquisitions; risks posed by fluctuations in share price levels, exchange rates and interest rates, and general economic conditions; risks inherent in the Company’s and industry analysts’ forecasts or predictions of future uranium and vanadium price levels; fluctuations in the market prices of uranium, vanadium and copper, which are cyclical and subject to substantial price fluctuations; risks associated with the Company's existing long-term sales contracts expiring following the Company's 2018 deliveries, and all uranium sales after 2018 being required to be made at spot prices, unless the Company is able to enter into new long-term contracts at satisfactory prices in the future; failure to obtain suitable uranium sales terms at satisfactory prices in the future, including spot and term sale contracts; risks associated with asset impairment as a result of market conditions; risks associated with lack of access to markets and the ability to access capital; the market price of Energy Fuels’ securities; public resistance to nuclear energy or uranium extraction and recovery; risks associated with inaccurate or nonobjective media coverage of the Company's activities and the impact such coverage may have on the public, the market for the Company's securities, government relations, permitting activities and legal challenges, as well as the costs to the Company of responding to such coverage; uranium industry competition, international trade restrictions and the impacts on world commodity prices of foreign state subsidized production; risks associated with the Company's involvement in industry petitions for trade remedies, including the costs of pursuing such remedies and the potential for negative responses or repercussions from various interest groups, consumers of uranium and participants in other phases of the nuclear fuel cycle; risks related to higher than expected costs related to our Nichols Ranch Project and Canyon Project; risks related to our ability to recover copper from our Canyon Project ores; risks related to securities regulations; risks related to stock price and volume volatility; risks related to our ability to maintain our listing on the NYSE American and Toronto Stock Exchanges; risks related to our ability to maintain our inclusion in various stock indices; risks related to dilution of currently outstanding shares, from additional share issuances, depletion of assets or otherwise; risks related to our lack of dividends; risks related to recent market events; risks related to our issuance of additional common shares under our At-the-Market ("ATM") program or otherwise to provide adequate liquidity in depressed commodity market circumstances; risks related to acquisition and integration issues; risks related to defects in title to our mineral properties; risks related to our outstanding debt; and risks related to our securities. This list is not exhaustive of the factors that may affect our forward-looking statements. Some of the important risks and uncertainties that could affect forward-looking statements are described further under the section headings: Item 1. Description of the Business; Item 1A. Risk Factors; and Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations of this Annual Report. Although we have attempted to identify important factors that could cause actual results to differ materially 4 from those described in forward-looking statements, there may be other factors that cause results not to be as anticipated, estimated or intended. Should one or more of these risks or uncertainties materialize, or should underlying assumptions prove incorrect, actual results may vary materially from those anticipated, believed, estimated, or expected. We caution readers not to place undue reliance on any such forward-looking statements, which speak only as of the date made. Except as required by law, we disclaim any obligation to subsequently revise any forward-looking statements to reflect events or circumstances after the date of such statements or to reflect the occurrence of anticipated or unanticipated events. Statements relating to “Mineral Reserves” or “Mineral Resources” are deemed to be forward-looking statements, as they involve the implied assessment, based on certain estimates and assumptions that the Mineral Reserves and Mineral Resources described may be profitably extracted in the future. We qualify all the forward-looking statements contained in this Annual Report by the foregoing cautionary statements. 5 CAUTIONARY NOTE TO UNITED STATES INVESTORS CONCERNING DISCLOSURE OF MINERAL RESOURCES The Company is a U.S. Domestic Issuer for SEC purposes, most of its shareholders are U.S. residents and its primary trading market is the NYSE American. However, because the Company is also listed on the Toronto Stock Exchange ("TSX"), this Annual Report contains certain disclosure that satisfies the additional requirements of Canadian securities laws, which differ from the requirements of United States’ securities laws. Unless otherwise indicated, all reserve and resource estimates included in this Annual Report, and in the documents incorporated by reference herein, 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 (“CIM”) classification system. NI 43-101 is a rule developed by the Canadian Securities Administrators (the “CSA”) which establishes standards for all public disclosure an issuer makes of scientific and technical information concerning mineral projects. Canadian standards, including NI 43-101, differ significantly from the requirements of the United States Securities and Exchange Commission (the “SEC”), and reserve and resource information contained herein, or incorporated by reference in this Annual Report, and in the documents incorporated by reference herein, may not be comparable to similar information disclosed by companies reporting under only United States standards. In particular, and without limiting the generality of the foregoing, the term “resource” does not equate to the term “reserve” under SEC Industry Guide 7. Under United States standards, 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. Under SEC Industry Guide 7 standards, a “final” or “bankable” feasibility study is required to report reserves; the three-year historical average price, to the extent possible, is used in any reserve or cash flow analysis to designate reserves; and the primary environmental analysis or report must be filed with the appropriate governmental authority. The SEC’s disclosure standards under Industry Guide 7 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 United States standards in documents filed with the SEC. United States investors should also understand that “Inferred Mineral Resources” have a great amount of uncertainty as to their existence and 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. United States investors are cautioned not to assume that all or any part of Measured or Indicated Mineral Resources will ever be converted into mineral reserves. 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 pounds” or “contained ounces” in a resource estimate is permitted and typical 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. The requirements of NI 43-101 for identification of “reserves” are also not the same as those of the SEC, and reserves reported by the Company in compliance with NI 43-101 may not qualify as “reserves” under SEC Industry Guide 7 standards. Accordingly, information concerning mineral deposits set forth herein may not be comparable to information made public by companies that report in accordance with United States standards. Although the Company's primary trading market is the NYSE American, most of the Company's shareholders are U.S. residents, the Company is a U.S. domestic Issuer for SEC purposes, and the Company is required to report its financial results under U.S. Generally Accepted Accounting Principles ("GAAP"), as a company incorporated in Canada and also listed on the TSX, unless otherwise indicated, in order to comply with both Canadian and U.S. requirements, Energy Fuels estimates and reports our mineral resources and mineral reserves according to the definitions set forth in NI 43-101. All reserves that are reported in this Form 10- K are estimated in accordance with the definitions set forth in NI 43-101. The Company does not have any reserves which conform to SEC Industry Guide 7 for reporting in the U.S. The definitions for each reporting standard are presented below with supplementary explanation and descriptions of the parallels and differences. CIM and NI 43-101 Definitions: • Feasibility Study: A “feasibility study” is a comprehensive technical and economic study of the selected development option for a mineral project that includes appropriately detailed assessments of applicable modifying factors, together with any other relevant operational factors and detailed financial analysis that are necessary to demonstrate, at the time of reporting, that extraction is reasonably justified (economically minable). The results of the study may reasonably serve as the basis for a final decision by a proponent or financial institution to proceed with, or finance, the development of the project. The confidence level of the study will be higher than that of a pre-feasibility study. 6 • • Indicated Mineral Resource1: An “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 applied to a measured mineral resource and may only be converted to a probable mineral reserve. Inferred Mineral Resource:2 An “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. Geological 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 applied 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. • Measured Mineral Resource:3 A “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 applied 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. • Mineral Reserve:4 A “mineral reserve” is the economically mineable part of a measured and/or indicated mineral resource. It includes diluting materials and allowances for losses which may occur when the mineral is mined or is extracted and is defined by studies at pre-feasibility or feasibility level as appropriate that include application of modifying factors. Such studies demonstrate that, at the time of reporting, extraction could reasonably be justified. The reference point at which mineral reserves are defined, usually the point where the ore is delivered to the processing plant, must be stated. It is important that, in all situations where the reference point is different, such as for a saleable product, a clarifying statement is included to ensure that the reader is fully informed as to what is being reported. The public disclosure of a mineral reserve must be demonstrated by a pre-feasibility study or feasibility study. • Mineral Resource:5 A “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. • Modifying Factors: “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. • Pre-Feasibility Study: A “pre-feasibility study” is a comprehensive study of a range of options for the technical and economic viability of a mineral project that has advanced to a stage where a preferred mining method, in the case of underground mining, or the pit configuration, in the case of an open pit, is established and an effective method of mineral processing is determined. It includes a financial analysis based on reasonable assumptions on the modifying factors and the evaluation of any other relevant factors which are sufficient for a qualified person, acting reasonably, to determine if all or part of the mineral resource may be converted to a mineral reserve at the time of reporting. A pre- feasibility study is at a lower confidence level than a feasibility study. • Probable Mineral Reserve:6 A “probable mineral reserve” is the economically mineable part of an indicated, and in some circumstances, a measured mineral resource. The confidence in the modifying factors applied to a probable mineral reserve is lower than that applied to a proven mineral reserve. • Proven Mineral Reserve:7 A “proven mineral reserve” is the economically minable part of a measured mineral resource. A proven mineral reserve implies a high degree of confidence in the modifying factors. 1 SEC Industry Guide 7 does not recognize the designation of a deposit as an “Indicated Mineral Resource.” 2 SEC Industry Guide 7 does not recognize the designation of a deposit as an “Inferred Mineral Resource.” 3 SEC Industry Guide 7 does not recognize the designation of a deposit as a “Measured Mineral Resource.” 4 SEC Industry Guide 7 does not recognize “reserves” calculated in accordance with NI 43-101. 5 SEC Industry Guide 7 does not recognize the designation of a deposit as a “Mineral Resource.” 6 SEC Industry Guide 7 does not recognize “reserves” calculated in accordance with NI 43-101. SEC Industry Guide 7 requires a final or “bankable” feasibility study for the designation of a deposit as a “reserve” that must include adequate information on mining, processing, metallurgical, economic, and other relevant factors that demonstrate, at the time of reporting, that economic 7 extraction is justified. Further, all necessary permits must have been filed with the appropriate regulatory authorities including the primary environmental analysis or report. • Qualified Person:8 A “qualified person” is an individual who: (a) is an engineer or geoscientist with a university degree, or equivalent accreditation, in an area of geoscience or engineering, relating to mineral exploration or mining; (b) has at least five years of experience in mineral exploration, mine development or operation, or mineral project assessment, or any combination of these, that is relevant to his or her professional degree or area of practice; (c) has experience relevant to the subject matter of the mineral project and technical report; (d) is in good standing with a professional association; and (e) in the case of a professional association in a non-Canadian jurisdiction, has a membership designation that (i) requires attainment of a position of responsibility in his or her profession that requires the exercise of independent judgment; and (ii) requires (A) a favorable confidential peer evaluation of the individual’s character, professional judgment, experience, and ethical fitness; or (B) a recommendation for membership by at least two peers, and demonstrated prominence or expertise in the field of mineral exploration or mining. SEC Industry Guide 7 Definitions: • Exploration Stage: Includes all issuers engaged in the search for mineral deposits (reserves) which are not in either the development or production stage. • Development Stage: Includes all issuers engaged in the preparation of an established commercially mineable deposit (reserves) for its extraction which are not yet in the production stage. • Probable (Indicated) Reserves: Reserves for which quantity and grade and/or quality are computed from information similar to that used for proven (measured) reserves, but the sites for inspection, sampling and measurement are farther apart or are otherwise less adequately spaced. The degree of assurance, although lower than that for proven reserves, is high enough to assume continuity between points of observation. • Production Stage: Includes all issuers engaged in the exploitation of a mineral deposit (reserve). • Proven (Measured) Reserves: Reserves for which (a) quantity is computed from dimensions revealed in outcrops, trenches, working, or drill holes; grade and/or quality are computed from the results of detailed sampling and (b) the sites for inspection, sampling and measurement are spaced so closely and the geological character is so well defined that size, shape, depth, and mineral content of reserves are well established. • Reserve: That part of a mineral deposit which could be economically and legally extracted or produced at the time of the reserve determination. Note: as the Company does not have any mineral reserves within the meaning of SEC Industry Guide 7, it is considered to be in an Exploration Stage, regardless of its uranium recovery activities. GLOSSARY OF TECHNICAL TERMS The following defined technical terms are used in this Annual Report: • Assay: The testing of a metal or ore to determine its ingredients and quality. • Breccia: A rock in which angular fragments are surrounded by a mass of fine-grained materials. • Copper: A red-brown metal, the chemical element of atomic number 29. • Cut-off or cut-off grade: When determining economically viable mineral reserves, the lowest grade of mineralized material that can be mined economically. When determining mineral resources, the lowest grade of mineralized material included in the resource estimate. • eU3O8: This term refers to equivalent U3O8 grade derived by gamma logging of drill holes. • EA: Environmental Assessment prepared under NEPA for a mineral project. • EIS: Environmental Impact Statement prepared under NEPA for a mineral project. 7 SEC Industry Guide 7 does not recognize “reserves” calculated in accordance with NI 43-101. SEC Industry Guide 7 requires a final or “bankable” feasibility study for the designation of a deposit as a “reserve” that must include adequate information on mining, processing, metallurgical, economic, and other relevant factors that demonstrate, at the time of reporting, that economic extraction is justified. Further, all necessary permits must have been filed with the appropriate regulatory authorities including the primary environmental analysis or report. 8 SEC Industry Guide 7 does not require designation of a qualified person. 8 • Extraction: The process of physically extracting mineralized material from the ground. Exploration continues during the extraction process and, in many cases, mineralized material is expanded during the life of the extraction activities as the exploration potential of the deposit is realized. • 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. • In-situ recovery ("ISR"): The recovery, by chemical means, of the uranium component of a deposit without the physical extraction of uranium-bearing material from the ground. ISR utilizes injection of appropriate oxidizing chemicals into a uranium-bearing sandstone deposit by injection wells, with the uranium-bearing solution being removed by extraction wells; also referred to as “solution mining.” • 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. • Mineralized material: Material that contains mineralization (e.g., uranium, vanadium and/or copper) and that is not included in an SEC Reserve as it does not meet all of the criteria for adequate demonstration of economic or legal extraction. • National Instrument 43-101 (“NI 43-101”): The National Instrument regarding Canadian standards of disclosure for mineral projects. • NEPA: The United States National Environmental Policy Act of 1969, as amended. • Open pit: Surface mineral extraction in which the mineralized material is extracted from a pit or quarry. • Ore: Mineral bearing rock that can be mined, processed and concentrated profitably under current or immediately foreseeable economic conditions. Under SEC Industry Guide 7, a company may only refer to reserves (as that term is defined in SEC Industry Guide 7) as “ore.” • Ore body: Amostly solid and fairly continuous mass of in-ground mineralization estimated to be economically mineable. • Outcrop: That part of a geologic formation or structure that appears at the surface of the Earth. • PEA: A Preliminary Economic Assessment performed in accordance with NI 43-101. A Preliminary Economic Assessment is a study, other than a pre-feasibility study or feasibility study, which includes an economic analysis of the potential viability of mineral resources. • PO: Plan of Operations for a mineral project prepared in accordance with applicable United States Bureau of Land Management or United States Forest Service regulations. • Reclamation: 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. • RoD or Record of Decision: The final approval issued by the United States Bureau of Land Management or United States Forest Service for a PO. • SEC Industry Guide 7: U.S. reporting guidelines that apply to registrants engaged, or to be engaged, in significant mining operations. • 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” and the primary component of “yellowcake,” and is produced from uranium deposits. It is the most actively traded uranium-related commodity. 9 • 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.” • % U3O8 Eq: equivalent uranium grade calculated by combining uranium content and copper content by taking into account commodity price and recovery factors. • V2O5: Vanadium pentoxide, or the form of vanadium typically produced at the White Mesa Mill, also called “blackflake.” • Yellowcake: Another name for Uranium Concentrate. 10 General Development of the Business PART I ITEM 1. DESCRIPTION OF BUSINESS Corporate Structure The Company's corporate offices are in the Denver, Colorado metropolitan area, and all of its assets and employees are in the western United States, and are owned and operated by the Company's subsidiary, Energy Fuels Resources (USA) Inc., and its affiliates. The Company is an Ontario corporation. It was incorporated on June 24, 1987 in the Province of Alberta under the name “368408 Alberta Inc.” In October 1987, 368408 Alberta Inc. changed its name to “Trevco Oil & Gas Ltd.” In May 1990, Trevco Oil & Gas Ltd. changed its name to “Trev Corp.” In August 1994, Trev Corp. changed its name to “Orogrande Resources Inc.” In April 2001, Orogrande Resources Inc. changed its name to “Volcanic Metals Exploration Inc.” On September 2, 2005, the Company was continued under the Business Corporations Act (Ontario). On March 26, 2006, Volcanic Metals Exploration Inc. acquired 100% of the outstanding shares of “Energy Fuels Resources Corporation.” On May 26, 2006, Volcanic Metals Exploration Inc. changed its name to “Energy Fuels Inc.” On November 5, 2013, the Company amended its Articles to consolidate its issued and outstanding common shares on the basis of one post-consolidation common share for every 50 pre-consolidation Common Shares. The Company conducts its operations through its U.S. subsidiaries, which have their principal place of business and corporate office at 225 Union Blvd., Suite 600, Lakewood, Colorado 80228, USA. The Company’s website address is www.energyfuels.com. The registered office of Energy Fuels Resources (USA) Inc. is at 225 Union Blvd., Suite 600, Lakewood, Colorado 80228, USA, and the registered office of the Company is located at 82 Richmond Street East; Suite 308 Toronto, Ontario, M5C 1P1, Canada. The primary trading market for Energy Fuels’ common shares (the “Common Shares”) is the NYSE American under the trading symbol “UUUU,” and the Company’s common shares are also listed on the TSX under the trading symbol “EFR.” Energy Fuels is a U.S. domestic issuer for SEC reporting purposes and, in addition, is a reporting issuer in all of the Canadian provinces. Certain warrants issued by the Company are listed on the NYSE American under the symbol "UUUU-WT." and are also listed on the TSX under the symbol "EFR.WT". Options on Energy Fuels’ common shares are traded on The Chicago Board Options Exchange. The Designated Primary Market Maker for the options is Group One Trading, LP. KCG Americas LLC is the Company’s Market Maker on the NYSE American. In addition, Energy Fuels’ Cdn $20.9 million aggregate amount of convertible debentures are listed on the TSX under the symbol “EFR.DB.” The Company conducts its uranium extraction, recovery, and sales business, and owns its properties, through a number of subsidiaries. A diagram depicting the organizational structure of the Company and its active subsidiaries, including the name, country of incorporation, and proportion of ownership interest, is included as Exhibit 21.1 to this Annual Report. All of the Company’s U.S. assets are held directly or indirectly through the Company’s wholly-owned subsidiaries Energy Fuels Holdings Corp. (“EF Holdings”) and Strathmore Minerals Corp. (“Strathmore”). EF Holdings and Strathmore hold all or a portion of their uranium extraction, recovery, permitting, evaluation and exploration assets through a number of additional subsidiaries, as detailed below. Energy Fuels also owns a number of inactive subsidiaries which have no material assets or liabilities and do not engage in any material business activities. All of the Company's properties are operated by Energy Fuels Resources (USA) Inc. (“EFUSA”), a wholly-owned subsidiary of EF Holdings. In addition, the Company holds 9,439,857 shares of Virginia Energy Resources Inc. (TSXV:VUI; OTCQX:VEGYF) currently representing an approximate 16.5% equity interest in that company, and 14,250,000 common shares of enCore Energy Corp. (TSXV:UE) currently representing an approximate 12.8% equity interest in that company. Business Overview Energy Fuels is engaged in conventional and in situ recovery (“ISR”) uranium extraction and recovery, along with the exploration, permitting, and evaluation of uranium properties in the United States. Its corporate offices are in the Denver, Colorado metropolitan area, and all of its assets and employees are in the western United States. Energy Fuels owns the Nichols Ranch Uranium Recovery Facility in Wyoming (the “Nichols Ranch Project”), which is one of the newest uranium recovery facilities operating in the United States, and the Alta Mesa Project in Texas (the "Alta Mesa Project"), which is a fully-permitted ISR production facility currently on care and maintenance. In addition, Energy Fuels owns the White Mesa Mill in Utah (the “White Mesa Mill” or “Mill”), which is the only conventional uranium recovery facility operating in the United States. The Company also owns uranium and uranium/vanadium properties and projects in various stages of exploration, permitting, and evaluation, as well as fully- permitted uranium and uranium/vanadium projects, and a uranium/copper project, on standby. The White Mesa Mill can also recover vanadium as a by-product of mineralized material produced from certain of its projects in Colorado and Utah, and is 11 evaluating recovering copper as a by-product from a uranium/copper project in Arizona. In addition, Energy Fuels recovers uranium from other uranium-bearing materials not derived from conventional material, referred to as “alternate feed materials,” at its White Mesa Mill. ISR Operations The Company conducts its ISR activities through its Nichols Ranch Project in northeast Wyoming, which it acquired in June 2015 through its acquisition of Uranerz Energy Corporation (“Uranerz”), and its Alta Mesa Project in south Texas, which it acquired in June 2016 through its acquisition of Mesteña Uranium, LLC (“Mesteña”), which is now named EFR Alta Mesa LLC ("EFR Alta Mesa"). The Nichols Ranch Project includes: (i) a licensed and operating ISR processing facility (the “Nichols Ranch Plant”); (ii) licensed and operating ISR wellfields (the “Nichols Ranch Wellfields”); (iii) additional licensed ISR wellfields planned for future production (the “Jane Dough Property”), and; (iv) a licensed satellite ISR uranium project (the “Hank Project”), which will include an ISR processing plant (the “Hank Satellite Plant”) that, when constructed, will produce loaded-resin, and associated planned wellfields (the “Hank Property”). See “The Nichols Ranch ISR Project” under Item 2 below. Also through the acquisition of Uranerz, the Company acquired the Reno Creek property (the “Reno Creek Property”), West North Butte property (the “West North Butte Property”), and the North Rolling Pin property (the “North Rolling Pin Property”), as well as the Arkose Mining Venture (the “Arkose Mining Venture”), which is a joint venture of Wyoming ISR properties held 81% by Energy Fuels. The Company is currently under contract to sell the Reno Creek Property to Uranium Energy Corp. See “Non-Material Mineral Properties - Other ISR Projects” under Item 2 below. The Nichols Ranch Project is an operating ISR facility that recovers uranium through a series of injection and recovery wells. Using groundwater fortified with oxygen and sodium bicarbonate, uranium is dissolved within a deposit. The groundwater is then collected in a series of recovery wells and pumped to the Nichols Ranch Plant. The Nichols Ranch Plant creates a yellowcake slurry that is transported by truck to the White Mesa Mill, where it is dried and packaged into drums that are shipped to uranium conversion facilities. Construction of the Nichols Ranch Plant, other than the elution, drying and packaging circuits, was completed in 2013, and it commenced uranium recovery activities in the second quarter of 2014. In September of 2015, the Company commenced construction of an elution circuit at the Nichols Ranch Plant, which was completed and began operations in February 2016. During 2017, a total of 259,000 pounds of U3O8 were recovered from the Nichols Ranch Project. The Alta Mesa Project is a fully licensed, permitted and constructed ISR processing facility that has an operating capacity of 1.5 million pounds of uranium per year and comprises 195,501 contiguous acres of land. The Alta Mesa Project is currently on standby and ready to resume production as market conditions warrant; Alta Mesa is expected to be able to reach commercial production levels with limited required capital within approximately twelve months of a production decision. See “The Alta Mesa Project” under Item 2 below. Conventional Operations The Company conducts its conventional uranium extraction and recovery activities through its White Mesa Mill, which is the only operating conventional uranium and vanadium processing facility in the United States. The White Mesa Mill, located near Blanding Utah, is centrally located such that it can be fed by a number of the Company’s uranium, uranium/vanadium and uranium/copper projects in Colorado, Utah, Arizona and New Mexico, as well as by ore purchases or toll milling arrangements with third parties in the region as market conditions warrant. The White Mesa Mill is a 2,000 ton per day uranium recovery facility, which can also process vanadium as a by-product of mineralized material extracted from certain uranium/vanadium properties, and is evaluating recovering copper as a by-product from a uranium/copper project in Arizona. In addition, the Mill can recycle other uranium-bearing materials not derived from conventional ore, referred to as "alternate feed materials", for the recovery of uranium, alone or in combination with other metals. The White Mesa Mill has historically operated on a campaign basis, whereby mineral processing occurs as mill feed, contract requirements, and market conditions warrant. Over the years, the Company’s own, and third-party owned, conventional uranium properties in Utah, Colorado, Arizona and New Mexico have been both active and on standby, from time-to-time, in response to changing market conditions. From 2007 through 2014, running on a campaign basis, the White Mesa Mill recovered on average over 1 million pounds of U3O8 per year from conventional sources, including its La Sal Project, Daneros Project, and Tony M property in Utah; its Arizona 1 and Pinenut Projects in Arizona; and alternate feed materials. During 2015, the Mill recovered a total of 296,000 lbs. of U3O8, of which 25,000 pounds were recovered from conventional materials and the remainder from processing alternate feed materials (including 72,000 pounds for the account of a third party). During 2016, the Mill recovered a total of 680,000 lbs. of U3O8, of which 433,000 pounds were recovered from conventional materials from the Company's Pinenut Project and 248,000 pounds from processing alternate feed materials. During 2017, the Mill recovered 310,000 pounds from 12 processing pond solutions and 1,000,000 pounds from processing alternate feed materials, of which a total of 360,000 pounds were for the Company's account and 950,000 pounds were for the account of third parties. The Company’s Pinenut Project, where mineral extraction activities occurred until September 2015, is now depleted, and reclamation activities have commenced. The Company continues to receive and process alternate feed materials at the White Mesa Mill. At the Company’s permitted Canyon Project, an underground drilling project has been completed, and a new shaft was completed in the first quarter of 2018. The timing to extract and process mineralized material from the Canyon Project will be based on market conditions, available financing, and sales requirements. All of the Company’s other conventional properties and projects are currently in the permitting process or on standby pending improvements in market conditions. No third party conventional properties are active at this time. The Company also owns the Sheep Mountain Project (the “Sheep Mountain Project”), which is a conventional uranium extraction project located in Wyoming. Due to its distance from the White Mesa Mill, the Sheep Mountain Project is not expected to be a source of feed material for the Mill. The Sheep Mountain Project consists of permitted open pit and underground extraction components (the “Sheep Mountain Extraction Operation”) and a planned processing facility to process extracted mineralized material (the “Sheep Mountain Processing Operation”), which has not yet been permitted. The Company’s principal conventional properties include the following: • • • • • • • • the White Mesa Mill, a 2,000 ton per day uranium and vanadium processing facility, which is also evaluating recovering copper as a by-product from the Company's Canyon Project, located near Blanding, Utah, held through the Company’s subsidiary EFR White Mesa LLC. See “The White Mesa Mill” under Item 2 below; the Arizona Strip uranium properties located in north central Arizona, including: the Canyon Project, which is a fully- permitted uranium/copper project with all surface facilities and a new shaft in place (see “The Canyon Project” under Item 2 below); the Wate project (the “Wate Project”), which is a uranium deposit in the permitting stage; the Arizona 1 project (the “Arizona 1 Project”), which is a fully-permitted uranium project on standby; and the EZ properties (“EZ Properties”), which are uranium deposits in the exploration and evaluation stage. All of the Company’s Arizona Strip properties are held by the Company’s subsidiary EFR Arizona Strip LLC, with the exception of the Wate Project, which is held by the Company’s subsidiary Wate Mining Company LLC. See “Non-Material Mineral Properties – Other Conventional Projects – Arizona Strip” under Item 2 below; the Roca Honda uranium project (the “Roca Honda Project”), which is located near the town of Grants, New Mexico, held by the Company’s subsidiaries Strathmore Resources (US), Ltd., and Roca Honda Resources LLC. See “The Roca Honda Project” under Item 2 below; the Sheep Mountain Project, which is a uranium project located near Jeffrey City, Wyoming, including permitted open pit and underground components held by the Company’s subsidiary Energy Fuels Wyoming Inc. See “The Sheep Mountain Project” under Item 2 below; the Henry Mountains complex of uranium projects (the “Henry Mountains Complex”), located in south central Utah near the town of Ticaboo, which is comprised of the Tony M property (the “Tony M Property”) and the Bullfrog property (the “Bullfrog Property”), and which are held by the Company’s subsidiary EFR Henry Mountains LLC. See “The Henry Mountains Complex” under Item 2 below; the La Sal complex of uranium and uranium/vanadium projects (the “La Sal Project”) (see “The La Sal Project” under Item 2 below), the Whirlwind uranium/vanadium project (the “Whirlwind Project”), and the Sage Plain uranium/ vanadium project (the “Sage Plain Project”), all of which are located near the Colorado/Utah border (the “Colorado Plateau”) and, in addition to nearby exploration properties, are held by the Company’s subsidiary EFR Colorado Plateau LLC. See “Non-Material Mineral Properties – Other Conventional Projects – Colorado Plateau” under Item 2 below; the Daneros uranium project (the “Daneros Project”) located in the White Canyon district in southeastern Utah, which is held by the Company’s subsidiary EFR White Canyon Corp. See “The Daneros Project” under Item 2 below; and a number of non-core uranium properties, which the Company is evaluating for sale or abandonment, which are held in various of the Company’s subsidiaries. See “Non-Material Mineral Properties” under Item 2 below. Mineral Exploration Energy Fuels holds a number of exploration properties in the Colorado Plateau, White Canyon, Grants, Arizona Strip, and Powder River Basin Districts. Energy Fuels has conducted intermittent exploration drilling on numerous projects in the period from February 2007 through December 2013. Several of those projects have been abandoned or sold. No exploration drilling was performed in 2014, 2015, 2016 or 2017. See “Non-Material Mineral Properties” under Item 2 below. Development of the Business -- Major Transactions over the Past Five Years Over the past five years, the Company has completed the following major transactions: 13 • • • • • • • In October 2013, the Company acquired all of the outstanding shares of Strathmore Minerals Corp. Under that transaction, the Company acquired a 60% interest in the Roca Honda Project as well as the Company’s 100% interests in other properties and assets, some of which have since been sold. The Roca Honda Project was formerly held in a joint venture until the Company acquired full ownership of the project in May 2016 when it purchased Sumitomo Corporation's 40% interest in the project. (see “The Roca Honda Project – History” under Item 2 below). The Roca Honda Project and the remaining assets acquired in October 2013 are held in the Company’s subsidiary, Strathmore Resources (US), Ltd. In two transactions in 2014, the Company sold its interest in the Pinon Ridge uranium/vanadium mill project, which is located in western Colorado, that the Company had previously planned to develop, along with a number of other non- core uranium properties; In June 2015, the Company acquired all of the outstanding shares of Uranerz. Under that transaction, the Company acquired the Nichols Ranch Project, the Hank Project, the Reno Creek Property, the West North Butte Property, the North Rolling Pin Property, the Company’s interest in the Arkose Mining Venture, uranium sales contracts, and other assets, as well as the shares of Uranerz, which holds those assets; In two separate transactions in February and November of 2015, the Company acquired 100% ownership of the Wate Project through the acquisition of Wate Mining Company LLC; In June 2016, the Company acquired EFR Alta Mesa and its primary asset, the Alta Mesa Project; In November 2017, the Company announced that it had entered into an agreement to sell its non-core Reno Creek Property to Uranium Energy Corp. (see 2017 Corporate Developments, below); and In November 2017, the Company announced that it had entered into an agreement to acquire and extinguish royalties on its Nichols Ranch Project as well as acquire and hold royalties on nearby operating and permitting ISR uranium projects owned by Cameco Corporation (see 2017 Corporate Developments, below). 2017 Corporate Developments On May 17, 2017, the Board appointed Messrs. Benjamin Eshleman III and Robert W. Kirkwood to serve as Directors of the Company pursuant to the Board's power to increase the size of the Board by up to one-third in number between annual meetings of shareholders. Messrs. Glenn Catchpole and Ron Hochstein did not stand for re-election as Directors at the Company's Annual General Meeting of Shareholders, and therefore ceased to be Directors effective May 17, 2017. Effective June 12, 2017, Ames Brown resigned as a Director of the Company. Effective July 1, 2017, the Company appointed Mark S. Chalmers as President and Chief Operating Officer. On November 2, 2017, the Company announced that it had entered into an agreement to sell its non-core Reno Creek Property to Uranium Energy Corp. ("UEC") for $5.39 million, including $2.94 million of cash and $2.45 million shares of UEC that will be priced upon the closing of the transaction. The Company expects this transaction to be completed in Q1-2018. On November 13, 2017, the Company announced that it had entered into an agreement with Excalibur Industries to acquire and extinguish royalties on its Nichols Ranch Project as well as acquire and hold royalties on nearby operating and permitted ISR uranium projects owned by Cameco for approximately $3.5 million, subject to certain adjustments. This consideration will be payable in common shares at closing, which will be priced based on the volume-weighted average price ("VWAP") of Energy Fuels' shares on the NYSE American for the five most recent trading days ending on the last trading day prior to closing. Through the transaction, the Company will acquire a 6% - 8% sliding-scale gross proceeds production royalty on Energy Fuels' Nichols Ranch Project. This royalty also applies to other properties owned by the Company nearby. After closing, the Company expects to extinguish these royalties. Energy Fuels is also acquiring the 4% gross proceeds production royalty on Cameco's North Butte/ Brown Ranch Project ("North Butte"), the Ruby Ranch Project, and the Greasewood property. North Butte is a fully permitted and operational project that has been operated by Cameco as a satellite to their Smith Ranch-Highland ISR Project since 2013. This transaction is expected to close in the first half of 2018. On December 29, 2017, the Company amended its existing Controlled Equity Offering Sales Agreement with Cantor Fitzgerald & Co. (“Cantor”), to extend its ability to sell from time to time at its discretion, through Cantor as agent, common shares by way of an “at-the-market” offering (the “ATM”). Sales of the shares, if any, would occur by means of ordinary brokers’ transactions or block trades, with sales only being made on the NYSE American at market prices. Any decision to undertake sales of common shares pursuant to the ATM would be at the Company’s sole discretion. No common shares will be offered or sold through the ATM on the TSX. In connection with the ATM, the Company filed a prospectus supplement to its U.S. registration statement on Form S-3 (the “Registration Statement”), qualifying for distribution up to $30 million in common shares under the extended ATM. Company Strategy Energy Fuels intends to continue to strengthen its position as a leading uranium extraction and recovery company in the United States. Through the operating White Mesa Mill, the operating Nichols Ranch Project, the standby Alta Mesa Project, our large 14 uranium resource base, and existing conventional projects on standby, under construction, and in permitting, the Company’s strategy is to remain a unique and valuable call option on increases in the price of uranium, with significant scalability in improved market conditions. The Company is also pursuing revenue-generating opportunities at its White Mesa Mill through potential vanadium recovery and land clean-up work. The Company currently intends to maintain its ISR and conventional uranium recovery capabilities, its uranium resource base, and its scalability. However, continued weakness in uranium prices; an inability to generate sufficient revenues from alternate feed materials, potential land cleanup work and vanadium opportunities; and/or cash needs may dictate that the Company engage in further measures to maintain the value of this option. As a result of the foregoing, we intend to maintain the value of the Company as a call option on increases in the price of uranium, while conserving cash, by engaging in the following activities: • Produce from existing wellfields (wellfields #1 through #9) at Nichols Ranch and defer further wellfield development at Nichols Ranch until uranium prices improve; • Continue alternate feed processing and recovery of uranium from uranium dissolved in the Mill’s ponds, as well as pursue additional alternate feed materials and other sources of feed for the Mill, including potential vanadium recovery and material generated from land cleanup work; • • Complete installation of the sump at the Canyon Project in the first quarter of 2018, after which time all field activities will have been completed. The Company plans to continue to carry out engineering, procurement and construction management activities in 2018; • Continue evaluating the possibility of recovering copper at the White Mesa Mill as a by-product from the Canyon Project and pursue any permitting actions that may be required; • Continue to maintain standby projects and facilities (including the Canyon Project, Alta Mesa Project, the La Sal Project and the Daneros Project) in a state of readiness for the purpose of restarting mining activities, as market conditions may warrant. At this time, all of the Company’s conventional projects are expected to remain on standby until market conditions warrant restarting mining activities, or are in the evaluation or permitting process; • Continue permitting activities for the Roca Honda Project through the end of 2018; • Continue to pursue an appropriate trade remedy that properly recognizes the value of uranium produced in the U.S., as proposed in the Petition (see Subsequent Events, below); • Continue to evaluate the sale or abandonment of non-core assets that the Company does not believe contribute to shareholder value in order to reduce costs and/or receive sales proceeds; and • Continue to pursue additional cost cutting measures. Subsequent Events On January 16, 2018, the Company and Ur-Energy (the "Petitioners") announced that they had jointly filed a Petition (the "Petition") for Relief with the U.S. Department of Commerce ("DOC") 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 describes how uranium and nuclear fuel from state-owned and state-subsidized enterprises in Russia, Kazakhstan, Uzbekistan, and China potentially represent a threat to U.S. national security. The Petition seeks remedies 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 President's Buy American Policy. The remedies proposed by the Petitioners are expected to strengthen the U.S. uranium mining industry, bolster national defense, and improve supply diversification for U.S. utilities and their customers. It should be noted, however, that there can be no certainty of the outcome of the investigation or the recommendation of the Secretary, and therefore the outcome of this process is uncertain. On January 31, 2018, Stephen P. Antony retired from his position as Chief Executive Officer and a Director of the Company, and on February 1, 2018 Mark S. Chalmers was appointed President and Chief Executive Officer and a Director of the Company. On February 14, 2018, Mr. W. Paul Goranson, the former Executive Vice President, Operations, was appointed as Chief Operating Officer of the Company, reporting to the President and Chief Executive Officer of the Company, and Mr. Matthew 15 Tarnowski, the former Controller of the Company, was appointed as Chief Accounting Officer and Controller of the Company, reporting to the Chief Financial Officer of the Company. On March 1, 2018, Daniel G. Zang resigned from his position as Chief Financial Officer of the Company, and on March 2, 2018, Mr. David C. Frydenlund, the former Senior Vice President, General Counsel and Corporate Secretary of the Company, was appointed as Chief Financial Officer, General Counsel and Corporate Secretary of the Company, reporting to the President and Chief Executive Officer of the Company. On March 8, 2018, the Board appointed Barbara A. Filas as a Director of the Company effective March 12, 2018, to fill the vacancy created by the resignation of Mr. Ames Brown from the Board. Uranium Sales The Company has four existing contracts, which require deliveries of 650,000 pounds of U3O8 in 2018. Of this, a total of 400,000 pounds of U3O8 is required to be sourced from the Company’s uranium recovery operations, while Energy Fuels has the option to fulfill the remaining 250,000 pounds of U3O8 from the Company’s uranium recovery operations and/or open market purchases. At December 31, 2017, the Company had approximately 615,000 pounds of finished goods inventory from the Company’s uranium recovery operations. In 2018, the Company expects to have sufficient existing inventory or uranium recovery to meet all of its commitments to sell 650,000 pounds of uranium under its existing contracts. Of the 650,000 pounds of expected sales in 2018, 50,000 pounds are being sold at $24.75 per pound, 400,000 pounds are being sold at a fixed price of $61.30 per pound, and 200,000 pounds are being sold at a 0.5% discount to spot prices in effect at the times of delivery. Additional selective spot sales may be made in 2018 as necessary to generate cash for operations. Overview of Uranium Market The primary commercial use of uranium is to fuel nuclear power plants for the generation of electricity. All of the uranium extracted from Energy Fuels’ projects is expected to be used for this purpose. According to the World Nuclear Association (“WNA”), as of January 2018, there are currently 447 operable nuclear reactors world-wide, which required approximately 169 million pounds of U3O8 fuel in 2017 at full operation. Worldwide there are currently 58 new reactors under construction with an additional 157 reactors on order or in the planning stage, and another 351 which have been proposed. According to data from TradeTech LLC (“TradeTech”), the world continues to require more uranium than it produces from primary extraction, largely due to increasing uranium demands in Asia. The gap between demand and primary supply is filled by stockpiled inventories and secondary supplies. According to the WNA, the United States currently has 99 operating reactors, two reactors under construction, and another 35 reactors on order, planned or proposed. According to the Nuclear Energy Institute ("NEI"), the United States produced approximately 19.7% of its electricity from nuclear technology and avoided 554 million metric tons of carbon dioxide emissions in 2016. According to the U.S. Energy Information Agency (“EIA”), U.S. utilities purchased approximately 56.5 million pounds of U3O8 in 2016. However, in 2016 the U.S. only produced approximately 2.9 million pounds of U3O8. As a result, in 2016, the U.S. fulfilled only about 5% of its demand from domestic primary mine production. According to published EIA data, the U.S. produced 2.42 million pounds of U3O8 in 2017, including 1.47 million pounds of mine production and 0.95 million pounds of previously mined production that was reprocessed at the Company’s White Mesa Mill. Uranium is not traded on an open market or organized commodity exchange such as the London Metal Exchange, although the New York Mercantile Exchange provides financially-settled uranium futures contracts. Typically, buyers and sellers negotiate transactions privately and directly. Spot uranium transactions typically involve deliveries that occur immediately and up to 12 months in the future. Term uranium transactions typically involve deliveries that occur more than 12 months in the future, with long-term transactions involving delivery terms of at least three years. Uranium prices, both spot and term, are published by two independent market consulting firms, TradeTech and The Ux Consulting Company (“Ux”), on a weekly and monthly basis. Other brokers, including Numerco Ltd., Uranium Markets LLC, and Evolution Markets Inc., also publish daily broker average uranium prices. The spot and term prices of uranium are influenced by a number of global factors. For example, both the spot and term prices of uranium were negatively impacted by the accident at the Fukushima Daiichi Nuclear Plant in March 2011. The events at Fukushima created heightened concerns regarding the safety of nuclear plants and led to both temporary and permanent closures of nuclear plants around the world. The Fukushima incident has created downward pressure on uranium prices over the past seven years, 16 which is still being felt today. In contrast, China is pursuing an aggressive nuclear program, with 38 units now operating, 20 new units under construction, 39 units which are planned, and 143 units that have been proposed, according to January 2018 WNA data. Historically, most nuclear utilities have sought to purchase a portion of their uranium needs through mid- and long-term supply contracts, while other portions are bought on the spot market. Like sellers, buyers seek to balance the security of supply with the opportunity to take advantage of lower prices caused by volatility in prices. For this reason, both buyers and sellers track current spot and term prices for uranium carefully, make considered projections as to future prices, and negotiate with one another on transactions which each deems favorable to their respective interests. The graph below shows the monthly spot (blue line) and long-term (red line) uranium price from August 1969 until February 2018 as reported by TradeTech (not adjusted for inflation): To give a more recent perspective, the graph below shows the monthly spot (blue line) and long-term (red line) uranium price from January 2013 until February 2018 as reported by TradeTech (not adjusted for inflation): According to monthly price data from TradeTech, uranium prices during 2017 were up $3.50, or 17% for the year. Monthly spot prices began the year at $20.25 per pound of U3O8 on December 31, 2016 and ended the year at $23.75 per pound, reaching a high of $24.50 per pound for the month of January 2017 and a low of $19.95 per pound for the month of May 2017. According to Trade Tech, the spot price was $22.25 per pound on March 2, 2018. TradeTech price data also indicated that long-term U3O8 prices began 2017 at $30.00 per pound and ended 2017 at $31.00 per pound. The high long-term price for 2017 was $35.00 per pound for February, March, and April, and the low long-term price was $30.00 per pound for September and October. The long-term price at February 28, 2018 was $29.00 per pound. The Company believes the weak uranium markets are the result of excess uranium supplies caused by large quantities of secondary uranium extraction and excess inventories, the availability of low-priced spot material, the delayed restart of Japanese reactors, insufficient production cut-backs especially from state-owned and state- subsidized uranium and uranium fuel entities, premature reactor closures, and continued weak uranium demand. 17 Uranium Market Outlook and Uranium Marketing Strategy World demand for clean, reliable, and affordable baseload electricity is growing. As a result of the expected growth of nuclear energy, the Company believes the long-term fundamentals of the uranium industry remain positive. The Company believes prices must rise to higher levels to support the new primary production that will be required to meet the increasing demand we expect to see as more nuclear units are constructed around the world. According to TradeTech, world uranium requirements continue to exceed primary mine production, with the gap being bridged by secondary supplies and excess uranium inventories in various forms that have already been mined. In addition, it is the Company's belief that additional mine production cutbacks will be required to bring the market into balance in the short and medium terms. However, a large portion of global uranium production is state- owned and state-subsidized, and therefore not subject to normal market fundamentals. It is for this reason that the Company and Ur-Energy submitted the Petition to the U.S. Department of Commerce to initiate an investigation into the effects of uranium imports on U.S. national security. The Petitioners have proposed a quota system that limits uranium and uranium fuel imports, effectively reserving 25% of the U.S. nuclear market for U.S. uranium producers. At the current time, less than 5% of U.S. reactor demand is met by new production from U.S. uranium mines. The Company has believed for several years that uranium prices, and long-term contracting levels in particular, will need to rise to levels that are sufficient to incentivize new mine production. However, it is the Company's belief that non free-market forces have delayed this recovery. The Petition is intended to help address this situation. The Company believes prices likely hit a bottom in 2016, and despite considerable market uncertainty in 2017, the lows of 2016 were not repeated in 2017. In January 2017, it was announced that Kazakhstan would reduce 2017 uranium production by 10% (5 million+ lbs.) after several years of production increases. In November 2017, Cameco announced that it was temporarily suspending production from its McArthur River/Key Lake project for 10 months, which is among the largest and lowest cost uranium production facilities in the world. According to Royal Bank of Canada, this is expected to remove 17-18 million pounds of uranium production during 2018. If the suspension is extended, even more uranium will be removed from the market. In addition, in December 2017, Kazakhstan's state-owned uranium mining enterprise, Kazatomprom, announced further production cuts amounting to a total of 28.6 million pounds of uranium during 2018-2020. Although subsequent announcements by Kazakh government officials have put some doubt into the true scale of these cutbacks, it is the Company's belief that cuts to production in Kazakhstan will occur but not at the levels stated in the December 2017 announcement. On a longer-term basis, according to data from TradeTech and the WNA, Chinese utilities continue to aggressively build new reactors. In addition to China, according to the WNA, there are large numbers of new reactors under construction and in various stages of planning around the world. In the short- and medium-terms, market challenges remain. The world continues to be oversupplied with uranium, mainly due to large quantities of secondary and other inelastic uranium supplies (including enricher underfeeding and state-owned and state- subsidized uranium and nuclear fuel production), high levels of excess inventories, insufficient producer cut-backs, premature reactor shutdowns, delays in new reactor construction, two large new mines coming into production (Cigar Lake and Husab), and decreased demand due to Japanese reactors remaining offline for longer than expected. Though it should be noted that Husab continues to experience start-up delays and its 2.2 million lbs. of uranium production in 2017 did not meet TradeTech's forecast of 4 million lbs. In addition, conflicting announcements on the scale of Kazakh production cuts in 2018-2020 and the filing of the Petition by the Company and Ur-Energy may be causing some market participants to take a wait-and-see approach in the short- term. There remains a great deal of uncertainty in uranium prices regarding the timing and level of the recovery, as fundamental, political, technical, and other factors could cause prices to be significantly above or below currently expected ranges. Nevertheless, according to data from Trade Tech, global utilities have nearly 600 million lbs. of uncovered uranium requirements through 2025, which the Company expects will increase levels of market activity at some point in the future. The Company’s marketing strategy is to seek a base of earnings and cash flow through sales of a portion of its uranium into term contracts, to the extent such contracts are available at satisfactory prices. To gain exposure to increasing uranium prices, the Company seeks to sell a portion of its planned uranium extraction into contracts with market-related formulas, if available at satisfactory prices, and through future spot and term sales. Further exposure to increasing uranium prices can be generated through the Company’s ability to bring additional uranium extraction online in the future in response to increasing prices, which can be sold on a market-related or fixed basis at then prevailing prices. During 2017, the pricing on all of the Company’s contracts, other than the spot contract referenced above, were at their floors or at prices fixed by the contract. During 2017, the Company sold 520,000 pounds of U3O8 at a weighted- average price of $47.05 per pound. This included 320,000 pounds of sales under contracts at a weighted average price of $62.72 per pound and 200,000 pounds into contracts based on spot market prices at a weighted average price of $21.99 per pound. In 2018, the Company expects to sell a total of 650,000 pounds of U3O8 into its four existing contracts at pricing expected to average approximately $48.00 per pound based on the fixed prices contained in three of the contracts and current forecasts of spot prices and price inflation in the other contract. In Q1-2018 the Company amended its remaining long-term contracts with one customer, so that all remaining deliveries of 400,000 lbs. under the contracts will occur in April 2018 at a fixed price of $61.30 18 per pound; including moving 200,000 lbs. of deliveries originally scheduled for 2019 and 2020 up to April 2018. The Company also has a contract for the delivery of 50,000 lbs. in Q1-2018 at a fixed price of $24.75 per pound and a contract for the delivery of 200,000 lbs. in 2018 with pricing at a 0.5% discount to the spot price at the time of delivery. Additional selective spot sales may be made in 2018 as necessary to generate cash for operations. As a result of these amendments, the Company will have no further long-term contractual obligations following its 2018 deliveries. All uranium sales after 2018 will therefore be at spot prices and unhedged, unless the Company enters into new long-term contracts at satisfactory prices in the future. The Vanadium Market The White Mesa Mill has historically recovered vanadium as a by-product of uranium from certain of its properties on the Colorado Plateau, most notably from the La Sal Project, as well as from properties owned by third-parties on the Colorado Plateau through toll milling and similar arrangements, when the price of vanadium has been high enough to justify its recovery. The Mill’s most recent vanadium recovery occurred in 2013 when it recovered 1.5 million pounds of vanadium. Vanadium is a metallic element that, when converted into ferrovanadium ("FeV") (an alloy of vanadium and iron), is used primarily as an additive to strengthen and harden steel. According to market consultant Roskill, over 90% of FeV is used in the steel industry. In addition, vanadium continues to see interest in energy storage technologies, including vanadium redox flow batteries. China is the largest global producer of vanadium, accounting for roughly 44% of production in 2016 with additional production coming from Russia, South Africa, and Brazil (Roskill). Vanadium (as V2O5) prices were up sharply in 2017, beginning the year at $5.03 per pound, and ending the year at $9.75 per pound, reaching a high of $11.13 per pound in September 2017 (Metal Bulletin information received from the U.S. DOE). Vanadium prices are currently at $14.25 per pound. According to Roskill, prices have risen primarily as a result of tightening supplies in China, including the shutdown of vanadium producing facilities for environmental reasons. In addition, the closure of the Evraz Highveld facility in South Africa has added to market tightness (Roskill). On the demand side, increasingly stringent building requirements, particularly in China, are requiring the use of rebar that contains vanadium (Roskill). In the past, Energy Fuels has sold its vanadium both as V2O5 and as ferrovanadium (“FeV”) through spot sales to industry end- users and trading companies. No vanadium has been recovered or sold by the Company since 2013. The Company is currently evaluating certain opportunities in the vanadium space, including the potential to recover vanadium dissolved in the ponds at the White Mesa Mill, re-opening mines that contain vanadium resources, and/or recovering vanadium from non-ore sources. The Copper Market The White Mesa Mill has not produced copper. Due to the discovery of significant quantities of copper mineralization at the Canyon Project, the Company is investigating potential alternatives for recovering copper as a byproduct of uranium recovery at the White Mesa Mill. Copper is a malleable and ductile metallic element that has a number of industrial uses, including as a conductor of heat and electricity, as a building material, in industrial machinery, and as a component of certain metal alloys. According to the International Copper Study Group ("ICSG"), an intergovernmental organization that operates as the international commodity board for copper, the major product categories of the copper trade are: copper concentrates, copper blister and anode, refined copper cathode and ingots, copper scrap, copper semis, and a small amount of copper powders and compounds. Copper is mainly shipped by producers to fabricators as cathode, wire rod, billet, cake (slab), or ingot. Two of the key components of the copper market are the spot price (settlement price for a transaction today) and the future price. A futures or option contract defines the price of the delivery, the quantity of the product, the delivery date(s), and delivery location(s) and other aspects. Three main commodity exchanges provide the facilities to trade copper: the London Metal Exchange (LME), Commodity Exchange Division of the New York Mercantile Exchange (COMEX/NYMEX), and the Shanghai Futures Exchange (SHFE). According to the United States Geological Survey ("USGS"), the top global primary copper producers in 2016 were Chile, Peru, China, the United States, and Australia. In 2016, the U.S. had 24 mines that recovered copper with the top copper producing states being Arizona, New Mexico, Utah, Nevada, and Montana. In addition in 2016, the U.S. had three primary smelters, three electrolytic and four fire refineries, and fifteen electrowinning facilities that operated. According to Mining.com, the top copper producing companies globally are Codelco, Freeport-McMoRan, Glencore International, BHP Billiton, and Southern Copper. In addition to primary mining, recycling is also a significant source of copper, and recycled copper is indistinguishable from primary copper (ICSG). According to Investopedia, the price of copper is driven by a number of factors including strength and weakness in the U.S. dollar, oil prices, global demand, including China, the cost of production, labor relations, natural disasters/phenomena, and geopolitical events. The spot price of copper rose by approximately 28% during 2017 (London Metal Exchange). According to Goldman Sachs, the price of copper rose in 2017 primarily due to currency effects, global growth, and demand factors. Copper prices are currently at $3.08 per pound. Competition 19 The uranium industry is highly competitive. The Company competes with mining and exploration companies for uranium sales, the acquisition of uranium mineral properties, and the procurement of equipment, materials and personnel necessary to explore, develop, and extract uranium from such properties. There is competition for a limited number of uranium acquisition opportunities, including competition with other companies having substantially greater financial resources, staff and facilities than the Company. As a result, the Company may encounter challenges in acquiring attractive properties, and exploring and advancing properties currently in the Company’s portfolio. In addition, Energy Fuels competes with other uranium recovery companies, along with traders, brokers, financial institutions, converters, enrichers, and other market actors, including some that are state-owned and state-subsidized, for uranium sales. Due to the Company’s limited capital and personnel and the relative size of its operations, the Company may be at a competitive disadvantage compared to some other companies with regard to exploration and, if warranted, development of mining properties and securing uranium sales. The Company believes that competition for acquiring mineral prospects and completing uranium sales will continue to be intense in the future. The availability of funds for exploration, evaluation, permitting and construction of uranium projects is limited, and the Company may find it difficult to compete with larger and more established uranium exploration and production companies for capital. The Company’s inability to continue exploration, advancement, and the acquisition of new properties due to lack of funding could have a material adverse effect on the Company’s future operations and financial position. Government Regulation The Company’s properties and facilities are subject to extensive laws and regulations which are overseen and enforced by multiple federal, state and local authorities. These laws govern exploration, construction, extraction, recovery, processing, exports, various taxes, labor standards, occupational health and safety, waste disposal, protection and remediation of the environment, protection of endangered and protected species, toxic and hazardous substances, and other matters. Uranium minerals exploration, extraction, recovery, and processing are also subject to risks and liabilities associated with the perceived potential for pollution of the environment and disposal of waste products occurring as a result of such activities. Compliance with these laws and regulations may impose substantial costs on the Company and will subject the Company to significant potential liabilities. Changes in these regulations could require the Company to expend significant resources to comply with new laws or regulations or changes to current requirements and could have a material adverse effect on the Company’s business operations. Environmental Regulations Exploration, development, and extraction activities are subject to certain environmental regulations which may prevent or delay the continuance of our activities. In general, our exploration, evaluation, and extraction 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. Specifically, we are subject to legislation regarding emissions into the environment, water discharges, and storage and disposition of hazardous wastes. In addition, legislation has been enacted which requires facility sites to be reclaimed in accordance with such legislation. Compliance with these laws and regulations has not had a material effect on our operations or financial condition to date. Uranium milling in the U.S. is primarily regulated by the United States Nuclear Regulatory Commission (the “NRC”) pursuant to the Atomic Energy Act of 1954, as amended. Its primary function is to ensure the protection of employees, the public, and the environment from radioactive materials, and it also regulates most aspects of the uranium recovery process. The NRC regulations pertaining to uranium recovery facilities are codified in Title 10 of the Code of Federal Regulations. On August 16, 2004, the State of Utah became an Agreement State for the regulation of uranium mills. This means that the primary regulator for the White Mesa Mill is now the State of Utah Department of Environmental Quality (“UDEQ”) rather than the NRC. At that time, the Mill’s NRC Source Material License was transferred to the State of Utah and became a Radioactive Materials License, which was recently renewed in January 2018. The State of Utah incorporates, through its own regulations or by reference, all aspects of Title 10 pertaining to uranium recovery facilities. When the State of Utah became an Agreement State, it required that a Groundwater Discharge Permit (“GWDP”) be put in place for the White Mesa Mill. The GWDP is required for all similar facilities in the State of Utah, and specifically tailors the implementation of the state groundwater regulations to the Mill site. The State of Utah requires that every operating uranium mill have a GWDP, regardless of whether or not the facility discharges to groundwater. The GWDP for the Mill was finalized and implemented in March 2005 and recently renewed in January 2018. The White Mesa Mill also maintains a permit approval for air emissions with the UDEQ, Division of Air Quality. 20 Conventional uranium extraction is subject to regulation by a number of agencies including: (1) local county and municipal government agencies; (2) the applicable state divisions responsible for mining and protecting the environment within Utah, Colorado, Arizona, New Mexico, Texas and Wyoming; (3) the BLM and the United States Forest Service (the “USFS”) on public lands under their jurisdiction; (4) the U.S. Mine Safety and Health Administration (“MSHA”); (5) the United States Environmental Protection Agency (the “EPA”) for radon emissions from underground mines; and (6) other federal agencies (e.g., U.S. Fish and Wildlife Service, U.S. Army Corp. of Engineers, and DOE), where certain conditions exist. In addition, a uranium processing facility at the Sheep Mountain Project will be subject to regulation under the NRC, as a uranium processing facility and for permanent disposal of the resulting tailings. The provisions of the Atomic Energy Act and its regulations that are applicable to uranium milling also apply to our ISR facilities in Wyoming and Texas. The Nichols Ranch Project and the Alta Mesa Project each have a Source Material license. The Nichols Ranch Source Material License was issued by the NRC. However, because Texas is an Agreement State, the Alta Mesa Source Material License was issued by the Texas Commission on Environmental Quality. ISR facilities are also regulated by the State of Wyoming and State of Texas, respectively, and the EPA under the Clean Water Act, the Clean Air Act and the Resource Conservation and Recovery Act. In addition, ISR wellfields require an Underground Injection Control Permit under the Safe Drinking Water Act, as administered by the EPA. ISR operations are subject to regulations by the U.S. Occupational, Safety and Health Administration (“OSHA”), rather than MSHA. Reclamation bonds or the equivalent have been posted for each of the Company’s material properties that have structures or facilities. Energy Fuels is required to have export licenses issued by the NRC for its uranium exports. Such licenses are obtained by the Company as required. Land Tenure The Company’s land holdings are held either by leases from the fee simple owners (private parties or the State) or unpatented mining claims located on property owned and managed by the U.S. Federal Government. Annual fees must be paid to maintain unpatented mining claims, but work expenditures are not required. Holders of unpatented mining claims are generally granted surface access to conduct mineral exploration and extraction activities. However, additional permits and plans are generally required prior to conducting exploration or mining activities on such claims. On July 9, 2009, BLM issued a Notice of Proposed Withdrawal (“2009 Notice”) under which it proposed that a total of approximately one million acres of public lands around the Grand Canyon National Park be withdrawn from location and entry under the Mining Law of 1872 (the “Mining Law”), subject to valid existing rights. In the 2009 Notice, BLM stated that the purpose of the withdrawal, if determined to be appropriate, would be to protect the Grand Canyon watershed from any adverse effects of locatable hardrock mineral exploration and mining. The 2009 Notice segregated the lands from location and entry under the mining laws for up to two years to allow time for various studies and analyses, including appropriate NEPA analysis. In order to allow more time for BLM to complete its NEPA analysis, the U.S. Department of the Interior (the “DOI”) published Public Land Order 7773 on June 21, 2011, which effected a six-month emergency withdrawal of the area. The emergency withdrawal prevented the lands from being open to location and entry under the Mining Law upon expiration of the two-year segregation while the DOI completed the decision–making process on the proposed withdrawal. The emergency withdrawal was effective July 21, 2011 to January 20, 2012. During the two-year segregation and six month emergency withdrawal, the BLM, along with its cooperating agencies, completed various studies and analyses of resources in the withdrawal area, including an EIS under NEPA. These studies and analyses were undertaken to provide the basis for the final decision regarding whether or not to proceed with the proposed withdrawal or to select an alternative action. Based on this analysis, on January 9, 2012, the DOI announced its final decision to withdraw from location and entry under the Mining Law, subject to valid existing rights, the total of approximately one million acres of lands originally proposed in the 2009 Notice (the “Withdrawn Lands”), for a 20-year period. Lawsuits challenging this decision were filed by various industry groups and interested parties. No new mining claims may be filed on the Withdrawn Lands and no new Plans of Operations may be approved, other than Plans of Operations on mining claims that were valid at the time of withdrawal and that remain valid at the time of plan approval. Whether or not a mining claim is valid must be determined by a mineral examination conducted by BLM or USFS, as applicable. The mineral examination, which involves an economic evaluation of a project, must demonstrate the existence of a locatable mineral resource and that the mineral resource constitutes the discovery of a valuable mineral deposit. 21 All of the Company’s properties located on the Arizona Strip, with the exception of its Wate property and certain exploration properties held by the Company’s subsidiary, Arizona Strip Partners LLC, are located within the Withdrawn Lands. A mineral examination on the Company’s EZ Project will need to be completed by BLM, in conjunction with its review of the Company’s proposed Plan of Operations for that project. Mineral examinations were not required for the Company’s Arizona 1 and Pinenut projects, which had previously approved Plans of Operations and were recently active. Although the Company’s Canyon Project also has an approved Plan of Operation, and a mineral examination is not required, the USFS performed a mineral examination on that project in 2012 and concluded that the Canyon Project’s claims constitute valid existing rights. The USFS also concluded that no additional approvals are required on the Canyon Project. The Company believes that all of its material projects within the Withdrawn Lands are on valid mining claims that will each withstand a mineral examination. However, market conditions may postpone or prevent the performance of mineral examinations on certain properties and, if a mineral examination is performed on a property, there can be no guarantee that the mineral examination would not result in one of more of the Company’s mining claims being considered invalid, which could prevent a project from proceeding. Further, there have been efforts to create a National Monument on the Withdrawn Lands, and additional lands, near the Grand Canyon National Park. These efforts have included proposed legislation which was introduced in Congress and lobbying of the President of the United States to create a National Monument utilizing his executive powers under the Antiquities Act of 1906. However, in December 2016, President Obama decided not to grant monument status to the 1.7 million acres proposed for inclusion. In addition, President Obama designated the Bears Ears National Monument by executive order in December of 2016, which comprised 1.35 million acres of land in San Juan County, Utah. The designated land included a portion of the County road which the Company relies on for access to its Daneros Project as well as abutted a portion of the property boundary of the White Mesa Mill and encompassed two water sampling sites the Company monitors for the Mill. In December, 2017, President Trump issued a Proclamation that amended President Obama’s 2016 Proclamation and reduced the monument to two parcels encompassing a total of 201,876 acres, releasing 1.15 million acres. That Proclamation has been challenged in Federal Court. The closest boundaries of the reduced monument to any of the Company’s operations are respectively approximately 6 miles from the White Mesa Mill and approximately 15 miles from the Daneros Project. It is possible that the Daneros Project and/or the White Mesa Mill could become subject to additional requirements, restrictions and costs if the original designation is upheld in Court. Employees As of the date of this Annual Report, the Company and its subsidiaries have approximately 117 full-time employees. We operate in established mining areas where we have found sufficient available personnel for our business plans. Available Information Detailed information about us is or will be contained in our annual reports on Form 10-K, current reports on Form 8-K, proxy statements and other reports, and amendments to those reports, that we file with or furnish to the SEC. Prior to January 1, 2016, we were a foreign private issuer subject to limited periodic disclosure and current reporting requirements of the United States Securities Exchange Act of 1934, as amended (the “Exchange Act”), so we did not file Forms 10-K or 10-Q prior to January 2016. These reports, filed after January 1, 2016, are now available free of charge on our website, www.energyfuels.com, as soon as reasonably practicable after we electronically file such reports with or furnish such reports to the SEC. However, our website and any contents thereof should not be considered to be incorporated by reference into this document. We will furnish copies of such reports free of charge upon written request to our Investor Relations department. You can contact our Investor Relations department at: Energy Fuels Inc. 225 Union Blvd., Suite 600 Lakewood, Colorado, 80228 Tel: 303.974.2140 Fax: 303.974.2141 Toll Free: 1.888.864.2125 E-mail: investorinfo@energyfuels.com Additionally, our Code of Ethics, Audit Committee Charter, and certain Company policies are available on our website. We will furnish copies of such information free of charge upon written request to our Investor Relations department. 22 ITEM 1A. RISK FACTORS Our failure to successfully address any of the risks and uncertainties described below could have a material adverse effect on our business, financial condition and/or results of operations, and the trading price of our Common Shares may fluctuate widely. We cannot assure you that we will successfully address these risks or other unknown risks that may affect our business. The following information pertains to the outlook and conditions currently known to Energy Fuels that could have a material impact on the financial condition of Energy Fuels. Other factors may arise in the future that are currently not foreseen by management of Energy Fuels that may present additional risks in the future. Current and prospective security holders of Energy Fuels should carefully consider these risk factors. We are subject to the risks normally encountered by Companies in the mineral extraction industry. We are subject to the risks normally encountered by companies in the mineral extraction industry, such as: • • • • • • • • the discovery of unusual, or unexpected geological formations; accidental fires, floods, earthquakes, volcanic eruptions, and other natural disasters; unplanned power outages and water shortages; controlling water and other similar mining hazards; operating labor disruptions and labor disputes; the ability to obtain suitable or adequate machinery, equipment, or labor; our liability for potential pollution or other hazards; and other known and unknown risks involved in the conduct of exploration, development, and operation of mines, extraction and recovery facilities, and mills, along with the market for uranium. The development of mineral properties is affected by many factors, including, but not limited to: the cost of operations; variations in the grade of mineralized material; fluctuations in metal markets; costs of extraction and processing equipment; availability of equipment and labor; labor costs and possible labor strikes; government regulations, including without limitation, regulations relating to taxes, royalties, allowable extraction or production, importing and exporting of minerals; foreign exchange; employment; worker safety; transportation; and environmental protection. Our results of operations are significantly affected by the market price of uranium, vanadium and copper, which are cyclical and subject to substantial price fluctuations. Our earnings and operating cash flow are and will be particularly sensitive to the long and short term changes in the market price of uranium, vanadium and copper. Among other factors, these prices also affect the value of our resources, reserves, and inventories, as well as the market price of our Common Shares. Market prices are affected by numerous factors beyond our control. With respect to uranium, such factors include, among others: demand for nuclear power; political and economic conditions in uranium producing and consuming countries; public and political response to a nuclear incident; reprocessing of used reactor fuel, the re-enrichment of depleted uranium tails and the enricher practice of underfeeding; sales of excess civilian and military inventories (including from the dismantling of nuclear weapons; the premature decommissioning of nuclear power plants; and from the build-up of Japanese utility uranium inventories as a result of the Fukushima incident) by governments and industry participants; uranium supply, including the supply from other secondary sources; and production levels and costs of production. With respect to vanadium, such factors include, among others: demand for steel; the potential for vanadium to be used in advanced battery technologies; political and economic conditions in vanadium producing and consuming countries; world production levels; and costs of production. With respect to copper, such factors include, among others: emerging market demand and urbanization in countries such as China, with associated increases in construction activity; the strength of the homebuilding industry, generally; the use of substitutes, such as aluminum for power cables, electrical equipment, automobile radiators and cooling tubes; supply disruptions, such as labor disputes at major producing mines or natural disasters; and oil prices, which can impact the cost of energy required to recover copper. Other factors relating to the price of uranium, vanadium and copper include: levels of supply and demand for a broad range of industrial products; substitution of new or different products in critical applications for our existing products; expectations with respect to the rate of inflation; the relative strength of the US dollar and of certain other currencies; interest rates; global or regional political or economic crises; regional and global economic conditions; and sales of uranium, vanadium and copper by holders in response to such factors. If prices are below our cash costs of extraction or recovery and remain at such levels for any sustained period, we may determine that it is not economically feasible to continue commercial extraction or recovery at any or all of our projects or other facilities and may also be required to look for alternatives other than cash flow to maintain our liquidity until 23 prices recover. Our expected levels of uranium recovery and business activity are dependent on our expectation and the industry’s expectations of uranium, vanadium and copper prices, which may not be realized or may change. In the event we conclude that a significant deterioration in expected future uranium prices has occurred, we will assess whether an impairment allowance is necessary which, if required, could be material. The recent fluctuations in the price of many commodities is an example of a situation over which we have no control and which could materially adversely affect us in a manner for which we may not be able to compensate. There can be no assurance that the price of any minerals recovered from our properties will be such that any deposits can be operated at a profit. Our profitability is directly related to the market price of uranium, vanadium and copper recovered. We may from time to time undertake commodity and currency hedging programs, with the intention of maintaining adequate cash flows and profitability to contribute to the long term viability of the business. We anticipate selling forward in the ordinary course of business if, and when, we have sufficient assets and recovery to support forward sale arrangements, and forward sale arrangements are available on suitable terms. There are, however, risks associated with forward sale programs. If we do not have sufficient recovered product to meet our forward sale commitments, we may have to buy or borrow (for later delivery back from recovered product) sufficient product in the spot market to deliver under the forward sales contracts, possibly at higher prices than provided for in the forward sales contracts, or potentially default on such deliveries. In addition, under forward contracts, we may be forced to sell at prices that are lower than the prices that may be available on the spot market when such deliveries are completed. Although we may employ various pricing mechanisms within our sales contracts to manage our exposure to price fluctuations, there can be no assurance that such mechanisms will be successful. There can also be no assurance that we will be able to enter into term contracts for future sales of uranium, vanadium or copper at prices or in quantities that would allow us to successfully manage our exposure to price fluctuations. Our properties do not contain mineral reserves under SEC Industry Guide 7, and many of the Company’s properties, projects, and facilities are not economic at today’s commodity prices. Our properties do not contain any mineral reserves under SEC Industry Guide 7. See “Cautionary Note to United States Investors Concerning Disclosure of Mineral Reserve and Mineral Resource Estimates,” above. At current uranium and vanadium prices, many of our properties, projects, and facilities are not economic for uranium, and for some properties uranium and/or vanadium, extraction, recovery, or processing. At our Canyon Project, we are currently evaluating the possibility of recovering copper as a by-product along with uranium and the impact of any recovered copper on the economics of that project at current uranium prices. We intend to continue to hold, and in certain cases advance, a number of those properties, projects, and facilities in anticipation of possible future increases in the prices of uranium and/or vanadium, as the case may be. However, there can be no assurance that uranium and/or vanadium prices will ever, or within a reasonable time period, increase to the levels required to advance those properties or, in the case of projects or facilities on standby, to resume exploration, extraction, recovery, or processing activities at those projects or facilities. Similarly, there can be no assurance that the value of any copper recovered as a by-product at the Canyon Project will be sufficient to advance that project without increases in the price of uranium and/or copper. We continue to hold such properties, projects, and facilities because we believe that uranium and/or vanadium prices are likely to rise to such levels within a reasonable time period and that the Company will be able to demonstrate a significant copper credit at the Canyon Project, and the ability to maintain scalability as commodity prices increase is a key component of our business strategy. However, as there is a cost associated with holding and in some cases maintaining on standby such properties, projects, or facilities, we continuously evaluate, on a case-by-case basis, such costs against the prospects for price increases, and may from time to time sell, drop or reclaim any such properties, projects, or facilities. We have currently identified a number of non-core properties and projects that we may sell, drop, or reclaim depending on current market conditions. The White Mesa Mill has historically been run on a campaign basis as sufficient feed materials are available, and there can be no assurance that sufficient mill feed will be available in the future to sustain future campaigns. The White Mesa Mill has historically operated on a campaign basis, whereby mineral processing occurs as mill feed, cash needs, contract requirements, and/or market conditions may warrant. Each milling campaign is subject to receipt of sufficient mill feed that would allow us to operate the Mill on a profitable basis and/or recover a portion of its standby costs. At current uranium and vanadium prices, all of our permitted conventional properties are on standby and our other conventional properties are either in the evaluation and permitting phase or inactive. Further, at these commodity prices, no third party conventional properties are operating to provide mill feed. In times of depressed commodity prices, when conventional mine production is on standby, the Mill has relied primarily on processing alternate feed materials. The Mill continuously seeks to identify and secure additional alternate feed materials and other sources of mill feed, such as materials from the clean-up of abandoned uranium mine sites. However, there can be no assurance that sufficient conventional ores, alternate feed materials and/ or other sources of mill feed will be available in the future that would allow us to operate the White Mesa Mill on a profitable basis and/or recover a portion of the Mill’s standby costs at any time. 24 We have entered into term sales contracts for a portion of our recovered uranium, and there can be no guarantee that we will be able to extend the terms of those contracts or enter into new term sales contracts in the future on suitable terms and conditions. The Company has entered into term sales contracts for a portion of our recovered uranium, which have historically resulted in uranium sales at prices in excess of spot prices. Those contracts have fixed delivery terms, and all of the Company’s existing long- term sales contracts will expire following the Company’s April 1, 2018 deliveries. As a result, all uranium sales after April 1, 2018 will be required to be made at spot prices and will be unhedged, unless the Company enters into new long-term contracts at satisfactory prices in the future. There can be no guarantee that the Company will be able to enter into long-term contracts for the delivery of a sufficient amount of uranium at satisfactory prices in the future. The failure to enter into new term sales contracts on suitable terms, would be expected to adversely impact our operations and mining activity decisions, and resulting cash flows and income. We are subject to global economic risks. In the event of a general economic downturn or a recession, there can be no assurance that our business, financial condition, and results of operations would not be materially adversely affected. During the past several years, the global economy faced a number of challenges. During the global financial crisis of 2007-8 economic problems in the United States and Eurozone caused deterioration in the global economy, as numerous commercial and financial enterprises either went into bankruptcy or creditor protection or had to be rescued by governmental authorities. Access to public financing was negatively impacted by sub-prime mortgage defaults in the United States, the liquidity crisis affecting the asset-backed commercial paper and collateralized debt obligation markets, and massive investment losses by banks with resultant recapitalization efforts. These types of challenges can impact commodity prices, including uranium, vanadium and copper, as well as currencies and global debt and stock markets. These types of challenges may impact our ability to obtain equity, debt, or other financing on terms commercially reasonable to us, or at all. Additionally, these types of factors, as well as other related factors, may cause decreases in asset values that are deemed to be other than temporary, which may result in impairment losses. If these types of challenges occur, or if there is a material deterioration in general business and economic conditions, our operations could be adversely impacted and the trading price of our securities could be adversely affected. The price of our Common Shares is subject to volatility. Securities of mining companies have experienced substantial volatility and downward pressure in the recent past, often based on factors unrelated to the financial performance or prospects of the companies involved. These factors include macroeconomic conditions in North America and globally, and market perceptions of the attractiveness of particular industries. The price of our securities is also likely to be significantly affected by short-term changes in uranium, vanadium and copper prices, changes in industry forecasts of uranium, vanadium and copper prices, other mineral prices including oil and natural gas, currency exchange fluctuation, or in our financial condition or results of operations as reflected in our periodic earnings reports. Other factors unrelated to our performance that may have an effect on the price of our securities include the following: the extent of research coverage available to investors concerning our business may be limited if investment banks with research capabilities do not follow our securities; lessening in trading volume and general market interest in our securities may affect an investor's ability to trade significant numbers of our securities; the size of our public float and the exclusion from market indices may limit the ability of some institutions to invest in our securities; and a substantial decline in the price of our securities that persists for a significant period of time could cause our securities to be delisted from an exchange, further reducing market liquidity. Our exclusion from certain market indices may reduce market liquidity or the price of our securities. If an active market for our securities does not continue, the liquidity of an investor's investment may be limited and the price of our securities may decline. If an active market does not exist, investors may lose their entire investment. As a result of any of these factors, the market price of our securities at any given point in time may not accurately reflect our long-term value. Securities class-action litigation often has been brought against companies in periods of volatility in the market price of their securities, and following major corporate transactions or mergers and acquisitions. We may in the future be the target of similar litigation. Securities litigation could result in substantial costs and damages and divert management's attention and resources. Exploration, development, extraction, mining, recovery and milling of minerals, and the transportation and handling of the products recovered, are subject to extensive federal, state and local laws and regulations. These regulations govern, among other things; acquisition of the property or mineral interests; maintenance of claims; tenure; expropriation; prospecting; exploration; development; construction; extraction and mining; recovery, processing, milling and production; price controls; exports; imports; taxes and royalties; labor standards; occupational health; waste disposal; toxic substances; water use; land use; Native American consultations and accommodations; environmental protection and remediation; endangered and protected species; mine, mill and other facility decommissioning and reclamation; mine safety; transportation safety and emergency response; and other matters. Compliance with such laws and regulations has increased the costs of exploring, drilling, developing, constructing, operating and closing of our mines, mills, plants and other extraction, recovery and processing 25 facilities. It is possible that, in the future, the costs, delays and other effects associated with such laws and regulations may impact our decision as to whether to operate existing mines or facilities, or, with respect to exploration, development or construction properties, whether to proceed with exploration, development or construction, or that such laws and regulations may result in our incurring significant costs to remediate or decommission properties that do not comply with applicable environmental standards at such time. We expend significant financial and managerial resources to comply with such laws and regulations. We anticipate continuing to do so as the historic trend toward stricter government regulation may continue. There can be no assurance that future changes in applicable laws and regulations will not adversely affect our activities, operations or financial condition. New laws and regulations, amendments to existing laws and regulations or more stringent implementation of existing laws and regulations, including through stricter license and permit conditions, could have a material adverse impact on us, increase costs, cause a reduction in levels of, or suspension of, extraction or recovery and/or delay or prevent the construction or development of new mineral extraction properties. Mineral extraction is subject to potential risks and liabilities associated with pollution of the environment and the disposal of waste products occurring as a result of mineral exploration, extraction, mining, recovery and production. Environmental liability may result from mining or mineral extraction activities conducted by others prior to our ownership of a property. Failure to comply with applicable laws, regulations and permitting requirements may result in enforcement actions. These actions may result in orders issued by regulatory or judicial authorities causing activities or operations to cease or be curtailed, and may include corrective measures requiring capital expenditures, installation of additional equipment or remedial actions. Companies engaged in uranium exploration operations may be required to compensate others who suffer loss or damage by reason of such activities and may have civil or criminal fines or penalties imposed for violations of applicable laws or regulations. Should we be unable to fully fund the cost of remedying an environmental problem, the Company might be required to suspend activities or operations, declare bankruptcy, or enter into interim compliance measures pending completion of the required remedy, which could have a material adverse effect on the Company. To the extent that we are subject to uninsured environmental liabilities, the payment of such liabilities would reduce otherwise available earnings and could have a material adverse effect on us. In addition, we do not have coverage for certain environmental losses and other risks as such coverage cannot be purchased at a commercially reasonable cost. Compliance with applicable environmental laws and regulations requires significant expenditures and increases mine and facility, construction, development and operating costs. Worldwide demand for uranium is directly tied to the demand for electricity produced by the nuclear power industry, which is also subject to extensive government regulation and policies. The development of mineral properties and related facilities is contingent upon governmental approvals that are complex and time consuming to obtain and which, depending upon the location of the project, involve multiple governmental agencies. The duration and success of such approvals are subject to many variables outside of our control. Any significant delays in obtaining or renewing such permits or licenses in the future could have a material adverse effect on us. In addition, the international marketing of uranium is subject to governmental policies and certain trade restrictions, such as those imposed by the suspension agreement between the United States and Russia. Changes in these policies and restrictions may adversely impact our business. Public acceptance of nuclear energy and competition from other energy sources is unknown. Growth of the uranium and nuclear industry will depend upon continued and increased acceptance of nuclear technology as an economic means of generating electricity. Because of unique political, technological and environmental factors that affect the nuclear industry, including the risk of a nuclear incident, the industry is subject to public opinion risks that could have an adverse impact on the demand for nuclear power and increase the regulation of the nuclear power industry. 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. Sustained lower prices of oil, natural gas, coal and hydroelectricity may result in lower demand for uranium concentrates. Increased government regulation and technical requirements may make nuclear uneconomic, resulting in lower demand for uranium concentrates. Technical advancements and government subsidies in renewable and other alternate forms of energy, such as wind and solar power, could make these forms of energy more commercially viable and put additional pressure on the demand for uranium concentrates. Unfavorable media coverage of mining or nuclear energy could negatively affect our business. The Company is subject to media coverage relating to mining and the production of uranium and other forms of nuclear energy, some of which can be inaccurate, un-objective or politically motivated. As a result, the Company is frequently required to address or respond to such media coverage, which can be costly and time-consuming for the Company. Such inaccurate and non-objective media coverage can also negatively impact the public’s perception of the Company’s activities, the market for the Company’s securities, government relations, permitting activities and legal challenges. 26 The uranium industry is highly competitive. The international uranium industry, including the supply of uranium concentrates, is competitive. We market uranium in direct competition with supplies available from a relatively small number of uranium mining companies, from nationalized uranium companies, from uranium produced as a byproduct of other mining operations, from excess inventories, including inventories made available from decommissioning of nuclear weapons, from reprocessed uranium and plutonium, from used reactor fuel, and from the use of excess Russian enrichment capacity to re-enrich depleted uranium tails. Alarge quantity of current World production is foreign state subsidized and is inelastic, in that uranium market prices have little effect on the quantity supplied. In the case of foreign state subsidized production, uranium production is not subject to market factors and can be sold at prices that are less than the cost of production. The supply of uranium from Russia is, to some extent, impeded by a number of international trade agreements and policies. These agreements and any similar future agreements, governmental policies or trade restrictions are beyond our control and may affect the supply of uranium available in the United States and Europe. We compete with other mining companies and individuals for capital, mineral resources and reserves, and other mining assets, which may increase the cost of acquiring suitable claims, properties and assets, and we also compete with other mining companies to attract and retain key executives, employees and consultants. In addition, there are relatively few customers for uranium. There can be no assurance that we will continue to be able to compete successfully with our competitors in acquiring such properties and assets or in attracting and retaining skilled and experienced employees. Participation in Industry Trade Petition could have negative repercussions. The Company has participated in 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 describes how uranium and nuclear fuel from state-owned and state-subsidized enterprises in Russia, Kazakhstan, Uzbekistan, and China potentially 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 President's Buy American Policy. Although the Company believes the proposed remedies will strengthen the U.S. uranium mining industry, bolster national defense, and improve supply diversification for U.S. utilities and their customers, there is a potential for negative responses or repercussions to the proposed remedies from various special interest groups, consumers of uranium and participants in other phases of the nuclear fuel cycle, which could have a negative impact on the Company and its operations. In addition, the costs of pursuing the Petition and such remedies could be significant. It should also be noted that there can be no certainty of the outcome of the investigation or the recommendation of the Secretary, and therefore the outcome of this process is uncertain. We may be unable to timely pay our outstanding debt obligations, which may result in us losing some of our assets covered by mortgage and/or other security arrangements and may adversely affect our assets, results of operations, and future prospects. We may from time to time enter into arrangements to borrow money in order to fund our operations and expansion plans, and such arrangements may include covenants that restrict our business in some way. We may also from time to time acquire properties whereby certain payment obligations owed to the seller are paid by us over time, with the seller’s sole remedy for non-payment by us being reacquisition of the property. Events may occur in the future, including events out of our control that would cause us to fail to satisfy our obligations under our existing convertible Debentures, indebtedness owed to the State of Wyoming in connection with the Nichols Ranch Project described below, and/or other debt or financing instruments. In such circumstances, or if we were to default on our obligations under the debt or financing instruments, the amounts drawn under our agreements may become due and payable before the agreed maturity date, and we may not have the financial resources to repay such amounts when due. On November 26, 2013, our subsidiary, Uranerz entered into a Financing Agreement (the “Financing Agreement”) with Johnson County, Wyoming (the “County”) pursuant to which the County agreed to loan to Uranerz (the “Loan”) the proceeds from the sale of its $20,000,000 Taxable Industrial Development Revenue Bond, Series 2013, (the “Bond”) upon the terms and conditions set out in the Financing Agreement, for the purpose of financing the Nichols Ranch project. On November 26, 2013, in connection with the Financing Agreement and the Loan, Uranerz as mortgagor entered into a Mortgage & Security Agreement, pursuant to which Uranerz granted to the Trustee its rights and interests in the as-extracted collateral, contract rights relating directly or indirectly to the Lands (as identified in Exhibit A to the Mortgage & Security Agreement), general intangibles relating directly or indirectly to the Lands, fixtures or hereinafter located on the Lands or the Nichols Ranch ISR Plant, goods (including all inventory) and equipment, including without limitations the mineralized material and all personal property identified as owned by Uranerz in the Mortgage & Security Agreement to secure Uranerz’ obligations under the Financing Agreement, the Bond Purchase Agreement and the Note. The Mortgage & Security Agreement contains restrictive covenants, including, without limitation, that obligate Uranerz not to: (i) sell, convey, mortgage, pledge or otherwise dispose of or encumber the Encumbered Property (as set forth in the Mortgage and Security Agreement) without first securing the written consent of the mortgagee; (ii) cancel or terminate any Post Production Contracts (as set forth in the Mortgage and Security Agreement) or consent to or accept any cancellation or 27 termination thereof; (iii) amend or otherwise modify any Post Production Contracts or give any consent, waiver or approval thereunder; (iv) waive any default under or breach of any Post Production Contracts; or (v) take any other action in connection with the Post Production Contract which would impair the value of the interest or rights of Uranerz thereunder or which would impair the interests or rights of the mortgagee. The current principal amount outstanding on the loan is $10.02 million. If Uranerz is unable to timely satisfy its obligations under the Loan, including timely payment of the interest when due and payment of the principal amount at maturity and Uranerz is not able to successfully extend the maturity date or otherwise re-negotiate the terms of the Note, the Trustee will have rights under the Mortgage and Security Agreement to potentially seize or sell the secured properties and interests, equipment and personal property and the Nichols Ranch Plant to satisfy Uranerz’ obligations under the Loan. Any failure to timely meet Uranerz’ obligations under the Loan may adversely affect our assets, results of operations and future prospects. Further, although most, but not all, of our reclamation obligations are bonded, and cash and other assets have been reserved to secure a portion but not all of this bonded amount, to the extent the bonded amounts are not fully collateralized, we will be required to provide additional cash to perform our reclamation obligations when they occur. In addition, the bonding companies have the right to require increases in collateral at any time, failure of which would constitute a default under the bonds. In such circumstances, we may not have the financial resources to perform such reclamation obligations or to increase such collateral when due. Our Convertible Debentures will mature in 2020 and will be retired through either cash payment or the issuance of Common Shares. On July 24, 2012, the Company issued Cdn$22,000,000 aggregate principal amount of convertible debentures, with Cdn. $20,870,000 currently remaining, which were amended on August 4, 2016 (the “Debentures”). The Debentures will mature on December 31, 2020 and are convertible into Common Shares of the Company at the option of the holder at a conversion price, subject to certain adjustments, of Cdn$4.15 per share at any time prior to redemption or maturity. The Debentures may be retired at maturity either through the payment of cash or the issuance of Common Shares based on then prevailing market prices, at the Company’s option. This will either result in the allocation of cash to the retirement of the Debentures, which could be used for other purposes, or the issuance of Common Shares, which would result in dilution to shareholders. We may need additional financing in connection with the implementation of our business and strategic plans from time to time. The exploration, construction and development of mineral properties and the ongoing operation of mines and other facilities requires a substantial amount of capital and may depend on our ability to obtain financing through joint ventures, debt financing, equity financing or other means. We may accordingly need further capital in order to take advantage of further opportunities or acquisitions. Our financial condition, general market conditions, volatile uranium and vanadium markets, volatile interest rates, legal claims against us, a significant disruption to our business or operations, or other factors may make it difficult to secure financing necessary for the expansion of mining activities or to take advantage of opportunities for acquisitions. Further, continuing volatility in the credit markets may increase costs associated with debt instruments due to increased spreads over relevant interest rate benchmarks, or may affect our ability, or the ability of third parties we seek to do business with, to access those markets. Continued volatility in equity markets, specifically including energy and commodity markets, may increase the costs associated with equity financings due to a low share price, and the potential need to offer higher discounts and other value (e.g., warrants). There is no assurance that we will be successful in obtaining required financing as and when needed on acceptable terms, if at all. We are an “emerging growth company” and we cannot be certain if the reduced disclosure requirements applicable to emerging growth companies will make us less attractive to investors. We are an “emerging growth company” as defined in the JOBS Act. We will continue to qualify as an “emerging growth company” until the earliest to occur of: (a) the last day of the fiscal year during which we had total annual gross revenues of US $1,000,000,000 or more; (b) the last day of our fiscal year following the fifth anniversary of the date of the first sale of our common equity securities pursuant to an effective registration statement under the United States Securities Act of 1933, as amended (the “Securities Act”), such as our Form S-8 Registration Statement filed on March 31, 2014; (c) the date on which we, during the previous 3-year period, issued more than US$1,000,000,000 in non-convertible debt; or (d) the date on which we are deemed to be a ‘large accelerated filer.’ For so long as we continue to qualify as an emerging growth company, we will be exempt from the requirement to include an auditor attestation report relating to internal control over financial reporting pursuant to Section 404(b) of the Sarbanes-Oxley Act in our annual reports filed under the Exchange Act, even if we do not qualify as a “smaller reporting company,” as well as certain other exemptions from various reporting requirements that are applicable to other public companies. 28 The issuance of additional Common Shares may impact the trading price of our common shares. In times of depressed commodity prices, such as exist at this time, the Company may be required to raise additional capital to meet its liquidity requirements, through the issuance of additional common shares under our At the Market (“ATM”) program or otherwise, and/or dispose of assets. If we raise additional funding by issuing additional equity securities or securities convertible, exercisable, or exchangeable for equity securities, such financing may substantially dilute the interests of our shareholders and reduce the value of their investment. Similar dilution could result from the sale of assets to meet liquidity requirements. Mining operations involve a high degree of risk. The exploration, construction, development, operation, and other activities associated with mineral projects, along with the expansion of existing recovery operations and mining activities and restarting of projects, involve significant risks, including financial, technical, and regulatory risk. Development or advancement of any of the exploration properties in which we have an interest will only follow upon obtaining satisfactory exploration results, project permitting and licensing, and financing. The exploration, construction, development, operation and other activities associated with mineral projects involves significant financial risks over an extended period of time, which even a combination of careful evaluation, experience and knowledge may not eliminate. While discovery of a mine or other facility may result in substantial rewards, few properties which are explored are ultimately developed into producing mines or extraction or recovery facilities. Major expenses may be required to establish mineral resources and mineral reserves by drilling and to finance, permit, license, and construct extraction, mining, recovery and processing facilities. It is impossible to ensure that the current or proposed exploration, permitting, construction, or development programs on our mineral properties will result in a profitable commercial extraction, mining, or recovery operations. Whether a mineral deposit will be commercially viable depends on a number of factors, which include, among other things: the accuracy of resource and reserve estimates; the particular attributes of the deposit, such as its size, geology and grade; the ability to economically recover commercial quantities of the minerals; proximity to infrastructure and availability of personnel; financing costs; governmental regulations, including regulations relating to prices, taxes, royalties; the potential for litigation; land use; importing and exporting; and environmental and cultural protection. The construction, development, expansion and restarting of projects are also subject to the successful completion of engineering studies, the issuance of necessary governmental permits, the availability of adequate financing, and that engineering and construction timetables and capital costs are correctly estimated for our projects, including restarting projects on standby, and such construction timetables and capital costs are not affected by unforeseen circumstances. The effect of these factors cannot be accurately predicted, but the combination of these factors, along with others, may result in our not receiving an adequate return on invested capital. It is possible that actual costs and economic returns of current and new extraction, mining, or recovery operations may differ materially from our best estimates. It is not unusual in the mining industry for new mining operations and facilities to experience unexpected problems during the start-up phase, take much longer than originally anticipated to bring into a recovery or producing phase, require more capital than anticipated, operate at a higher cost than expected, and/or have reclamation liabilities which are higher than expected. There can be no assurance that as the Company mines its properties, or disposes of properties, the reduction of existing mineral resources through depletion or sales, will be replaced with new resources of comparable value. There is uncertainty in the estimation of mineral reserves and mineral resources. Our properties do not contain any mineral reserves under Industry Guide 7. See “Cautionary Note to United States Investors Concerning Disclosure of Mineral Reserve and Mineral Resource Estimates,” above. Mineral reserves and resources are statistical estimates of mineral content, based on limited information acquired through drilling and other sampling methods, and require judgmental interpretations of geology. Successful extraction requires safe and efficient mining and processing. Our mineral reserves and resources are estimates, and no assurance can be given that the estimated reserves and resources are accurate or that the indicated level of uranium, vanadium or copper will be produced economically or otherwise. Such estimates are, in large part, based on interpretations of geological data obtained from drill holes and other sampling techniques. Actual mineralization or formations may be different from those predicted. Further, it may take many years from the initial phase of drilling before production is possible, and during that time the economic feasibility of exploiting a discovery may change. Mineral reserve and resource estimates for properties that have not commenced extraction, production or recovery are based, in many instances, on limited and widely spaced drill-hole information, which is not necessarily indicative of the conditions between and around drill holes. Accordingly, such mineral resource and reserve estimates may require revision as more drilling information becomes available or as actual extraction, production or recovery experience is gained. It should not be assumed that all or any part of our mineral resources constitutes, or will be converted into, reserves. Market price fluctuations of uranium, vanadium or copper as applicable, as well as increased production and capital costs or reduced recovery rates, may render our proven and 29 probable reserves unprofitable to develop at a particular site or sites for periods of time or may render mineral reserves containing relatively lower grade mineralization uneconomic. Our business is subject to extensive environmental regulations that may make exploring, mining, or related activities expensive, and which may change at any time. We are required to comply with environmental protection laws and regulations and permitting requirements promulgated by federal agencies and various states and counties in which we operate and conduct our activities, in connection with extraction, mining, recovery and milling operations. The uranium industry is subject not only to the worker health and safety and environmental risks associated with all mining activities, but also to additional risks uniquely associated with uranium extraction, mining, recovery, and milling. We expend significant resources, both financial and managerial, to comply with these laws and regulations. The possibility of more stringent regulations exists in the areas of worker health and safety, storage of hazardous materials, standards for heavy equipment used in extraction, mining, recovery or milling, the disposition of wastes, the decommissioning and reclamation of exploration, extraction, mining, recovery, milling and in-situ sites, climate change and other environmental matters, each of which could have a material adverse effect on the cost or the viability of a particular project. We cannot predict what environmental legislation, regulations or policies will be enacted or adopted in the future or how future laws and regulations will be administered or interpreted. The recent trend in environmental legislation and regulation is generally toward stricter standards, and this trend is likely to continue in the future. This recent trend includes, without limitation, laws and regulations relating to air and water quality, mine and other facility reclamation, waste handling and disposal, the protection of certain species and the preservation of certain lands. These regulations may require the acquisition of permits or other authorizations for certain activities. These laws and regulations may also limit or prohibit activities on certain lands. Compliance with more stringent laws and regulations, as well as potentially more vigorous enforcement policies, stricter interpretation of existing laws and stricter permit and license conditions, may necessitate significant capital outlays, may materially affect our results of operations and business or may cause material changes or delays in our intended activities. There can be no assurance of our continued compliance or ability to meet stricter environmental laws and regulations and permit or license conditions. Delays in obtaining permits and licenses could impact expected production levels or increases in expected uranium extraction levels. Our operations may require additional analysis in the future including environmental, cultural, and social impact and other related studies. Certain activities require the submission and approval of environmental impact assessments. We cannot provide assurance that we will be able to obtain or maintain all necessary permits that may be required to continue operations or exploration and development of our properties or, if feasible, to commence construction, development, operation or other activities relating to mining facilities at such properties on terms that enable operations or activities to be conducted at economically justifiable costs. If we are unable to obtain or maintain, licenses, permits or other rights for construction or development of our properties, or otherwise fail to manage adequately future environmental issues, our uranium recovery operations and mining activities could be materially and adversely affected. On December 31, 2014, the EPA issued a proposed rule that would amend 10 CFR §192, “Health and Environmental Protection Standards for Uranium and Thorium Mill Tailings”, to add standards and regulation for ISR facilities such as the Nichols Ranch Project and the Alta Mesa Project. That proposed rule was withdrawn on January 3, 2017 and a new proposed rule was introduced on January 19, 2017. EPA is currently considering whether to proceed with the proposed rule. If EPA decides to proceed, the effect of the new proposed rule could be significant if promulgated. Any changes to rules or regulations that could significantly adversely impact any of our material projects could have a material adverse impact on the Company. In addition, former President Obama designated the Bears Ears National Monument by executive order in December of 2016, which comprises 1.35 million acres of land in San Juan County, Utah. As originally mapped, the monument boundary was on the western property line of the White Mesa Mill, and the western monument boundary was very close to the permit boundary of the Daneros Mine, which could impact access to the mine. A National Monument created on land where our projects are sited, or near the Company’s projects, along with any resulting changes to rules or regulations, could significantly adversely impact any of our material projects and could have a material adverse impact on the Company. The current Trump administration modified the designation of the Bears Ears National Monument on December 4, 2017 through Presidential Proclamation, which took effect on February 2, 2018. The revised boundaries have been moved well away from the White Mesa Mill property boundary as well as the Daneros Mine permit boundary. This revision of the monument boundaries is currently under legal challenge, but the Company does not expect that action to interfere with operations or activity. Opposition to mining may disrupt our business activities. In recent years, governmental agencies, non-governmental organizations, individuals, communities and courts have become more vocal and active with respect to their opposition to certain mining and business activities including with respect to production and uranium recovery at our facilities, such as the White Mesa Mill and the Canyon Project. This opposition may take on forms such as road blockades, applications for injunctions seeking to cease certain construction, development, extraction, mining and/or 30 milling or recovery activities, refusals to grant access to lands or to sell lands on commercially viable terms, lawsuits for damages or to revoke or modify licenses and permits, issuances of unfavorable laws and regulations, and other rulings contrary to our interests. These actions can occur in response to current activities or in respect of mines or facilities that are decades old. In addition, these actions can occur in response to our activities or the activities of other unrelated entities. Opposition to our activities may also result from general opposition to nuclear energy and mining. Opposition to our business activities are beyond our control. Any opposition to our business activities may cause a disruption to our business activities and may result in increased costs, and this could have a material adverse effect on our business and financial condition. We are subject to litigation and other legal proceedings arising in the normal course of business and may be involved in disputes with other parties in the future which may result in litigation. The causes of potential future litigation and legal proceedings cannot be known and may arise from, among other things, business activities, environmental laws, permitting and licensing activities, volatility in stock prices, or alleged failure to comply with disclosure obligations. The results of litigation and proceedings cannot be predicted with certainty, and may include injunctions pending the outcome of such litigation and proceedings. Failure to resolve any such disputes favorably may have a material adverse impact on our financial performance, cash flow and results of operations. We are subject to costs associated with decommissioning and reclamation of our properties. As owner and operator of the White Mesa Mill, the Nichols Ranch Project, the Alta Mesa Project, and numerous uranium and uranium/vanadium projects and other facilities located in the United States and certain permitting, construction, development and exploration properties, and for so long as we remain an owner thereof, we are obligated to eventually reclaim or participate in the reclamation of such properties. Most, but not all, of our reclamation obligations are bonded, and cash and other assets have been reserved to secure a portion, but not all, of this bonded amount. Although our financial statements will record a liability for the asset retirement obligation, and the bonding requirements are generally periodically reviewed by applicable regulatory authorities, there can be no assurance or guarantee that the ultimate cost of such reclamation obligations will not exceed the estimated liability to be provided on our financial statements. Further, to the extent the bonded amounts are not fully collateralized, we will be required to come up with additional cash to perform our reclamation obligations when they occur. Decommissioning plans for our properties have been filed with applicable regulatory authorities. These regulatory authorities have accepted the decommissioning plans in concept, not upon a detailed performance forecast, which has not yet been generated. Over time, further regulatory review of the decommissioning plans may result in additional decommissioning requirements, associated costs and the requirement to provide additional financial assurances, including as our properties approach or go into decommissioning. It is not possible to predict what level of decommissioning and reclamation (and financial assurances relating thereto) may be required in the future by regulatory authorities. We are subject to technical innovation and obsolescence in the uranium industry. Requirements for our products and services may be affected by technological changes in nuclear reactors, enrichment, and used uranium fuel reprocessing. These technological changes could reduce the demand for uranium. The cost competitiveness of our operations may be impacted through the development and commercialization of other uranium mining, milling, processing and other technologies. As a result, our competitors may adopt technological advancements that give them an advantage over the Company. Our mineral properties may be subject to defects in title. We have investigated our rights to explore and exploit all of our material properties and, to the best of our knowledge, those rights are in good standing. However, no assurance can be given that such rights will not be revoked, or significantly altered, to our detriment. There can also be no assurance that our rights will not be challenged or impugned by third parties, including by governments, surface owners, and non-governmental organizations. The validity of unpatented mining claims on U.S. public lands is sometimes difficult to confirm and may be contested. Due to the extensive requirements and associated expense required to obtain and maintain mining rights on U.S. public lands, our properties are subject to various title uncertainties which are common to the industry with the attendant risk that there may be defects in title. In addition, the Secretary of the Interior has withdrawn certain lands around the Grand Canyon National Park from location and entry under the Mining Laws. All of our material Arizona Strip properties, other than the Wate Property, are located on these withdrawn lands. No new mining claims may be filed on the withdrawn lands and no new plans of operations may be approved, other than plans of operations on mining claims that were valid at the time of withdrawal and that remain valid at the time of plan approval. Whether or not a mining claim is valid must be determined by a mineral examination conducted by BLM or USFS, as applicable. The mineral examination, which involves an economic evaluation of a project, must demonstrate the existence of a locatable mineral resource and that the mineral resource constitutes discovery of a valuable mineral deposit. We believe that all of our material Arizona Strip projects are on valid mining claims that would withstand a mineral examination. Further, our Arizona 31 1 Project has an approved PO which, absent modification, would not require a mineral examination. Although our Canyon project also has an approved PO, which, absent modification, would not require a mineral examination, the USFS performed a mineral examination at that mine in 2012, and concluded that the underlying mining claims are valid existing rights (a decision which is involved in a current court challenge). However, market conditions may postpone or prevent the performance of mineral examinations on certain other properties and, if a mineral examination is performed on a property, there can be no guarantee that the mineral examination would not result in one or more of our mining claims being considered invalid, which could prevent a project from proceeding. Certain of our properties, or significant portions thereof, are mineral leases that have fixed terms, both with State and private parties. Certain of our properties are subject to other agreements that may affect our ability to explore, permit, develop and operate them, including surface use, access and other agreements. There can be no guarantee that we will be able to renew or extend such leases and agreements on favorable terms or at all. The failure to renew any such leases or agreements could have a material adverse effect on our operations. 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 or facility 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) allow for administrative determinations that mining or similar activities would not be allowed in situations where undue degradation of the federal lands in question could not be prevented. If enacted, such legislation could 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 construction and development and the economics of existing operating mines and facilities. Passage of such legislation could adversely affect our financial performance. In addition to the withdrawal noted in the previous risk factor, there are currently other designated or proposed withdrawals of federal lands for the purposes of mineral location and development and proposed designations of national monuments which would have a similar effect as a withdrawal. While such proposals are not yet final and would require further federal action, if they were to occur, it is uncertain whether any such withdrawals or designations would affect in any manner our current mineral projects. Because we may be unable to secure access rights to certain of our properties, we may be unable to explore and/or advance such properties. We are currently in the process of negotiating and clarifying access rights to certain of our properties, such as the Roca Honda Project and the Wate Project, with private landholders. There can be no guarantee that we will be able to negotiate or clarify such access rights on favorable terms, or at all. The failure to negotiate or clarify such access rights on suitable terms could have a material adverse effect on our operations. We are subject to foreign currency risks. Our operations are subject to foreign currency fluctuations. Our operating expenses and revenues are primarily incurred in U.S. dollars, while some of our cash balances and expenses and our Debentures are measured in Canadian dollars. The fluctuation of the Canadian dollar in relation to the U.S. dollar will consequently have an impact on our profitability and may also affect the value of our assets and shareholders’ equity. In addition, the recent strengthening of the U.S. dollar relative to other currencies makes our mineral extraction and recovery less competitive in relation to similar activities in other countries. Current and future strengthening of the U.S. dollar in relation to the currencies of other countries can have a material impact on our cash flows and profitability, and affect the value of our assets and shareholders’ equity. We may not realize the anticipated benefits of previous acquisitions. We may not realize the anticipated benefits of acquiring: the Sheep Mountain Project in 2012; Denison Mines Corp’s US Mining Division in 2012, including the White Mesa Mill, certain of the Arizona Strip Properties, the Henry Mountains Complex, the La Sal Project, and the Daneros Project; Strathmore in 2013, including the Roca Honda Project; Uranerz in 2015, including the Nichols Ranch Project; and EFR Alta Mesa in 2016, including the Alta Mesa Project, due to integration, operational and uranium market challenges. Decreases in commodity prices have required us to place or maintain a number of acquired properties and facilities 32 on standby and to defer permitting and construction and development activities on certain other acquired assets, until market conditions warrant otherwise, and in some cases we have elected to sell or abandon certain of these properties at a loss. Our success following those acquisitions will depend in large part on the success of our management in integrating the acquired assets into the Company. Our failure to achieve such integration and to mine or advance such assets could result in our failure to realize the anticipated benefits of those acquisitions and could impair our results of operations, profitability and financial results. We prepare estimates of future uranium extraction and recovery, and there are no assurances that such estimates will be achieved. We may from time to time prepare estimates of future uranium extraction and recovery, or increases in uranium extraction and recovery, for particular operations, or relating to our ability to increase uranium extraction and recovery in response to increases in commodity prices, as market conditions warrant or otherwise. No assurance can be given that any such extraction and recovery estimates will be achieved, nor can assurance be given that extraction or recovery increases will be achieved in a cost effective or timely manner. Failure to achieve extraction and recovery estimates or failure to achieve extraction and recovery in a cost effective or timely manner could have an adverse impact on our future cash flows, earnings, results of operations and financial condition. These estimates are based on, among other things, the following factors: the accuracy of mineral resource and reserve estimates; the accuracy of assumptions regarding ground conditions and physical characteristics of mineralized materials, such as hardness and presence or absence of particular metallurgical characteristics; the accuracy of estimated rates and costs of extraction, recovery and processing; assumptions as to future commodity prices; assumptions relating to changes in laws, regulations or policies, or lack thereof, that could impact the cost and time required to obtain regulatory approvals, licenses and permits; assumptions relating to obtaining required licenses and permits in a timely manner, including the time required to satisfy environmental analyses, consultations and public input processes; assumptions relating to challenges to or delays in the licensing and permitting process; and assumptions regarding any appeals or lack thereof, or injunctions or lack thereof, relating to any approvals, licenses or permits. Our actual uranium extraction and recovery may vary from estimates for a variety of reasons, including, among others: actual mineralized material extracted, mined or recovered varying from estimates of grade, tonnage, dilution and metallurgical and other characteristics; short term operating factors relating to the mineral resources and reserves, such as the need for sequential construction or development of mineralized materials or deposits and the processing of new or different mineral grades; risk and hazards associated with extraction, mining and recovery; natural phenomena, such as inclement weather conditions, underground floods, earthquakes, pit wall failures and cave-ins; unexpected labor shortages or strikes; varying conditions in the commodities markets; and delays in obtaining or denial, challenges or appeals of regulatory approvals, licenses and permits or renewals of existing approvals, licenses or permits. In addition, the Company is evaluating recovering copper at the White Mesa Mill as a by-product with uranium from its Canyon Project. There can be no assurance that this evaluation will result in the Mill being able to recover copper at the Mill as a by- product on an economic basis. We depend on the issuance of license amendments and renewals which cannot be guaranteed. We maintain regulatory licenses and permits in order to operate our White Mesa Mill, Nichols Ranch Project and Alta Mesa Project, all of which are subject to renewal from time to time and are required in order to operate in compliance with applicable laws and regulations. In addition, depending on our business requirements, it may be necessary or desirable to seek amendments to one or more of our licenses or permits from time to time. While we have been successful in renewing our licenses and permits on a timely basis in the past and in obtaining such amendments as have been necessary or desirable, there can be no assurance that such license and permit renewals and amendments will be issued by applicable regulatory authorities on a timely basis or at all in the future. Mining, mineral extraction, recovery and milling are subject to a high degree of risk, and we are not insured to cover against all potential risks. Our operations and activities are subject to all of the hazards and risks normally incidental to exploration, construction, development, extraction and mining of mineral properties, and recovery, processing and milling, including: environmental hazards; industrial accidents; labor disputes, disturbances and unavailability of skilled labor; encountering unusual or unexpected geologic formations; rock bursts, pressures, cave-ins, flooding; periodic interruptions due to inclement or hazardous weather conditions; technological and processing problems, including unanticipated metallurgical difficulties, ground control problems, process upsets and equipment malfunctions; the availability and/or fluctuations in the costs of raw materials and consumables used in our production and recovery processes; the ability to procure mining and other equipment and operating and other supplies in sufficient quantities and on a timely basis; and other extraction, mining, recovery, milling, and processing risks, as well as risks associated with our dependence on third parties in the provision of transportation and other critical services. Many of the foregoing risks and hazards could result in damage to, or destruction of, our mineral properties or processing or recovery facilities, personal injury or death, environmental damage, delays in or interruption of or cessation of extraction, mining, production and recovery from our mines or processing facilities or in our exploration, construction or development activities, delay in or inability to receive regulatory approvals to 33 transport our uranium concentrates, or costs, monetary losses and potential legal liability and adverse governmental action. In addition, due to the radioactive nature of the materials handled in uranium extraction, mining, recovery, and processing, additional costs and risks are incurred by us on a regular and ongoing basis. While we may obtain insurance against certain risks in such amounts as we consider adequate, the nature of these risks are such that liabilities could exceed policy limits or could be excluded from coverage. There are also risks against which we cannot insure or against which we may elect not to insure. The potential costs which 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 future earnings, financial position and competitive position. No assurance can be given that such insurance will continue to be available or will be available at economically feasible premiums or that it will provide sufficient coverage for losses related to these or other risks and hazards. This lack of insurance coverage could result in material economic harm to us. We will need to continuously add to our mineral reserve and resource base and to our alternate feed materials. Our properties do not contain any mineral reserves under SEC Industry Guide 7. See “Cautionary Note to United States Investors Concerning Disclosure of Mineral Reserve and Mineral Resource Estimates,” above. Our material mineral resources are located at the Nichols Ranch Project, the Alta Mesa Project, the Canyon Project, the Roca Honda Project, the Sheep Mountain Project, the Henry Mountains Complex, the La Sal Project, and the Daneros Project. These projects are our primary sources (and potential sources) of current and future uranium concentrates. Unless other mineral resources or reserves are discovered or extensions to existing resource bodies are found, our sources of extraction, production and recovery for uranium concentrates will decrease over time as our current mineral resources are depleted. There can be no assurance that our future exploration, construction, development and acquisition efforts will be successful in replenishing our mineral resources or finding or developing reserves. In addition, while we believe that many of our properties will eventually engage in extraction or mining activities, there can be no assurance that they will be placed into such activities, or that they will be able to replace current extraction or mining activities. We also recover uranium from processing alternate feed materials at our White Mesa Mill. There can be no assurance that additional sources of alternate feed materials will be forthcoming in the future on commercially acceptable terms or otherwise, or that we will be successful in receiving all required regulatory approvals, licenses and permits on a timely basis to allow for the receipt and processing of any such alternate feed materials. Our sales of uranium and vanadium products expose us to the risk of non-payment. Our sales of uranium and vanadium products expose us to the risk of non-payment. We manage this risk by monitoring the credit worthiness of our customers and requiring pre-payment or other forms of payment security from customers with an unacceptable level of credit risk. Most of the Company’s sales are to major nuclear utilities, which pose a relatively low risk of non-payment due to their large size and capitalization. We are dependent on key personnel and qualified and experienced employees. Our success will largely depend on the efforts and abilities of certain senior officers and key employees, some of whom are approaching retirement. Certain of these individuals have significant experience in the uranium industry. The number of individuals with significant experience in this industry is small. While we do not foresee any reason why such officers and key employees will not remain with us, other than through retirement, if for any reason they do not, we could be adversely affected. We have not purchased key person life insurance for any of these individuals, other than for our Chief Executive Officer. Our success will also depend on the availability of qualified and experienced employees to work in our operations and our ability to attract and retain such employees. The number of individuals with relevant mining and operational experience in this industry, especially the U.S. uranium industry, is small. If we fail to maintain an effective system of internal control, we may not be able to accurately report financial results or prevent fraud. Internal controls over financial reporting are procedures designed to provide reasonable assurance that transactions are properly authorized, assets are safeguarded against unauthorized or improper use, and transactions are properly recorded and reported. Disclosure controls and procedures are designed to ensure that information required to be disclosed by a company in reports filed with securities regulatory agencies is recorded, processed, summarized and reported on a timely basis and is accumulated and communicated to a company’s management, including its chief executive officer and chief financial officer, as appropriate, to allow timely decisions regarding required disclosure. A control system, no matter how well designed and operated, can provide only reasonable, not absolute, assurance with respect to the reliability of reporting, including financial reporting and financial statement preparation. 34 We are dependent on business partners, government and third party consents. We have a number of joint ventures and other business relationships relating to our properties and projects, including key projects, such as the Arkose Mining Venture, which can restrict our ability to act unilaterally with respect to those projects in certain circumstances. There can be no assurances that we will be able to maintain relationships with our joint venture and business partners to allow for satisfactory exploration, permitting, construction, development, extraction, mining, recovery or milling relating to any such projects. Our operations and activities are also dependent from time to time on receiving government and other third party consents and approvals. There can be no assurances that all such consents and approvals will be forthcoming when required. Certain of our directors may be in a position of conflict of interest with respect to the Company due to their relationship with other resource companies. Some of our directors are also directors of other companies that are similarly engaged in the business of acquiring, exploring and developing natural resource properties. Such associations may give rise to conflicts of interest from time to time. In particular, one of the consequences will be that corporate opportunities presented to a director may be offered to another company or companies with which the director is associated, and may not be presented or made available to us. Our directors are required by law to act honestly and in good faith with a view to the best interests of the Company, to disclose any interest which they may have in any project or opportunity of the Company, and to abstain from voting on such matter. Conflicts of interest that arise will be subject to and governed by the procedures prescribed in our Code of Ethics and by the Business Corporations Act (Ontario). Our relationship with our employees may be impacted by changes in labor relations. None of our operations or activities currently directly employ unionized workers who work under collective agreements. However, there can be no assurance that our employees or the employees of our contractors will not become unionized in the future, which may impact our operations and activities. Any lengthy work stoppages may have a material adverse impact on our future cash flows, earnings, results of operations and financial condition. Mining, extraction, recovery, processing, construction, development, and exploration activities depend, to a substantial degree, on adequate infrastructure. Reliable roads, bridges, power sources, and water supply are important determinants affecting capital and operating costs. We consider the existing infrastructure to be adequate to support our proposed operations and activities. However, unusual or infrequent weather phenomena including drought, sabotage, government, or other interference in the maintenance or provision of such infrastructure could adversely affect our operations and activities, financial condition and results of operations. Because the probability of an individual prospect ever having reserves as defined by the SEC is not known, our properties may not contain any reserves, and any funds spent on exploration may be lost. We have no reserves as defined by SEC Industry Guide 7. Because the probability of an individual prospect ever having reserves is uncertain, our properties may not contain any reserves, and any funds spent on exploration, construction, development, extraction, and recovery may be lost. We do not know with certainty that economically recoverable uranium exists on any of our properties as defined by SEC Industry Guide 7. Further, although we are undertaking uranium extraction activities at our Nichols Ranch Project, our lack of established reserves means that we are uncertain as to our ability to continue to generate revenue from our operations. We may never discover uranium in commercially exploitable quantities and any identified deposit may never qualify as a commercially mineable (or viable) reserve. We will continue to attempt to acquire the surface and mineral rights on lands that we think are geologically favorable or where we have historical information in our possession that indicates uranium mineralization might be present. The exploration and, if warranted, construction relating to or development of mineral deposits involves significant financial and other risks over an extended period of time, which even a combination of careful evaluation, experience and knowledge may not eliminate. Few properties which are explored are ultimately developed into producing mines. Major expenditures are required to establish reserves by drilling and to construct mining and processing facilities at a site. Our uranium properties are all classified under SEC Industry Guide 7 to be at the exploration stage and do not contain any reserves at this time. It is impossible to ensure that the current or proposed exploration programs and other activities on properties in which we have an interest will result in the delineation of mineral reserves or in profitable commercial operations. Our operations and activities are subject to the hazards and risks normally incident to exploration and production of uranium, precious and base metals, any of which could result in damage to life or property, environmental damage and possible legal liability for such damage. While we may obtain insurance against certain risks, the nature of these risks is such that liabilities could exceed policy limits or could be excluded from coverage. There are also risks against which we cannot insure or against which we may elect not to insure. The potential costs which could be associated with any liabilities not covered by insurance, or in excess of insurance coverage, or compliance with applicable laws 35 and regulations may cause substantial delays and require significant capital outlays, adversely affecting our future earnings and competitive position and, potentially our financial viability. U.S. investors may have difficulty bringing actions and enforcing judgments under U.S. securities laws against an Ontario corporation. Although our primary trading market is the NYSE American, we have a majority of U.S. resident shareholders, are a U.S. Domestic Issuer for SEC purposes, and all of our assets, operations and employees are in the U.S., the Company was incorporated in Ontario, and as a result, investors in the United States or in other jurisdictions outside of Canada may have difficulty bringing actions and enforcing judgments against us, our directors, our executive officers and some of the experts named in this Annual Report on Form 10-K based on civil liabilities provisions of the federal securities laws or other laws of the United States or any state thereof or the equivalent laws of other jurisdictions of residence. Any attempt by U.S. President Trump to withdraw from or materially modify NAFTA and certain other international trade agreements could adversely affect our business, financial condition and results of operations, to the extent dependent on the jurisdiction of our incorporation. Although our primary trading market is the NYSE American, we have a majority of U.S. resident shareholders, are a U.S. Domestic Issuer for SEC purposes, and all of our assets, operations and employees are in the U.S., the Company was incorporated in Ontario. During the election campaign, then President-elect Trump made comments suggesting that he was not supportive of certain existing international trade agreements, including the North American Free Trade Agreement (“NAFTA”). At this time, it remains unclear what President Trump will or will not do with respect to these international trade agreements. If President Trump takes action to withdraw from or materially modify NAFTA or certain other international trade agreements, and such actions depend on the jurisdiction of our incorporation, then our business, financial condition and results of operations could possibly be adversely affected, depending on the nature of the action. The impact of the new tax legislation on our financial statements is uncertain and could be adverse. On December 22, 2017, U.S. tax legislation commonly known as the Tax Cuts and Jobs Act, or TCJA, was signed into law, significantly reforming the U.S. Internal Revenue Code. The TCJA, among other things, includes changes to U.S. federal tax rates, imposes significant additional limitations on the deductibility of interest, allows for the expensing of capital expenditures, puts into effect the migration from a “worldwide” system of taxation to a territorial system and modifies or repeals many business deductions and credits. We continue to examine the impact the TCJA may have on our business. We will evaluate the effect of the TCJA on our projection of minimal cash taxes or to our net operating losses. The estimated impact of the TCJA is based on our management’s current knowledge and assumptions and recognized impacts could be materially different from current estimates based on our actual results and our further analysis of the new law. None. ITEM 1B. UNRESOLVED STAFF COMMENTS 36 ITEM 2. DESCRIPTION OF PROPERTIES Cautionary Note to U.S. Investors: Information contained in this item differs from the disclosure requirements of the SEC applicable to U.S.-incorporated domestic issuers. This Item 2 and other sections of this Annual Report contain the terms “measured mineral resources,” “indicated mineral resources,” “inferred mineral resources,” “proven mineral reserves,” and “probable mineral reserves” as defined in accordance with NI 43-101. See “Cautionary Note to United States Investors Concerning Disclosure of Mineral Resources,” at the beginning of this Annual Report for definitions and further discussion on the differences between terms under NI 43-101 and SEC Industry Guide 7. 37 Overview Energy Fuels is engaged in conventional and ISR uranium extraction and recovery, along with the exploration, permitting and evaluation of uranium properties in the United States. ISR Uranium Activities The Company conducts its ISR recovery activities through its Nichols Ranch Project in northeast Wyoming, which it acquired in June 2015 through the acquisition of Uranerz, and its Alta Mesa Project in south Texas, which it acquired in June 2016 through the acquisition of EFR Alta Mesa. The Nichols Ranch Project includes: (i) the Nichols Ranch Plant; (ii) the Nichols Ranch Wellfields; (iii) the Jane Dough Property, and; (iv) the Hank Project, which includes the permitted but not constructed Hank Satellite Plant and the Hank Property. See “The Nichols Ranch ISR Project” below. Also through the acquisition of Uranerz, the Company acquired the Reno Creek Property, the West North Butte Property, the North Rolling Pin Property, and the Arkose Mining Venture, a joint venture of ISR properties held 81% by Energy Fuels. See “Non-Material Mineral Properties – Other ISR Projects,” below. The Alta Mesa Project has a fully-licensed and constructed ISR uranium recovery plant, with a design capacity of 1.5 million pounds of uranium concentrate per year. In order for Alta Mesa to be capable of uranium production, the Company will need to incur capital expenditures to develop wellfields. A decision to commence development will be made once uranium prices improve to a point where economic feasibility of the Alta Mesa Project is established. Conventional Uranium Activities The Company conducts its conventional uranium extraction and recovery activities through its White Mesa Mill, which is the only operating conventional uranium mill in the United States. The White Mesa Mill, located near Blanding, Utah, is centrally located such that it can be fed by a number of the Company’s uranium and uranium/vanadium projects in Colorado, Utah, Arizona and New Mexico, as well as by ore purchase or toll milling arrangements with third party miners in the region, as market conditions warrant. The Company also owns the Sheep Mountain Project in Wyoming, which is a conventional uranium project. Due to its distance from the White Mesa Mill, the Sheep Mountain Project is not expected to be a source of feed material for the Mill. The Sheep Mountain Project consists of the Sheep Mountain Extraction Operation, which is permitted, and the proposed Sheep Mountain Processing Operation, which is not permitted at this time. The Company’s principal conventional properties include the following: • • • • • • • • the White Mesa Mill. See “The White Mesa Mill” below; the Canyon Mine. See “The Canyon Mine” below; the Roca Honda Project. See “The Roca Honda Project” below; the Sheep Mountain Project. See “The Sheep Mountain Project” below; the Henry Mountains Complex comprised of the Tony M Property and the Bullfrog Property. See “The Henry Mountains Complex” below; the La Sal Project. See “The La Sal Project” below; the Daneros Project. See “The Daneros Project” below; the Arizona Strip uranium properties located in north-central Arizona, including: the Arizona 1 Project, the Wate Project, and EZ Project. See “Non-Material Mineral Properties – Other Conventional Projects – Arizona Strip” below; and • The Colorado Plateau uranium properties located in the Four Corners region of Colorado and Utah, including: the Whirlwind Project and the Sage Plain Project. See “Non-Material Mineral Properties – Other Conventional Projects – Colorado Plateau” below. The material projects are shown on the map above and are described in further detail below. Properties that the Company does not consider material are summarized at the end of this Item 2. Uranium and Vanadium Recovery History The following tables show the mineralized material processed and pounds of uranium and vanadium recovered from the Company’s projects and facilities from January 1, 2013 to December 31, 2017:(1) 38 Recovery History (1) Project or Source 2017 2016 2015 2014 2013 Alternate Feed Materials(2) Tons (000) NA(2) NA(2) NA(2) NA(2) NA(2) Ave. % U3O8 18.86% 27.98% 9.21% 16.94% 5.03% Recovered Pounds U3O8 (000) 1,004(3) 172(3)(4) 229(3) 391(3) 351(3) Tailing Solution Recycle & In-Circuit Material(5) Conventional Feed Materials Recovered Pounds U3O8 (000) 308 77 67 --- --- Tons (000) --- 45 Contained Grade % U3O8 Recovered Pounds U3O8 (000) --- --- 0.50% 431 --- --- --- 49 126 0.56% 0.26% 552 655 Recovered Pounds U3O8 (000) 259 335 273 200 --- Nichols Ranch(6) Alta Mesa Total Pounds of U3O8 Recovered (000) Total Pounds of V2O5 Recovered (000) Notes: Recovered Pounds (000) --- --- 1,571 1,015 --- --- --- 569 --- 3(7) 139(7) 1,146 1,145 --- 1,303 (1) Mineralized material is shown as being processed and pounds recovered during the year in which the materials were processed at the White Mesa Mill or at the Nichols Ranch Plant, which is not necessarily the year in which the materials were extracted from the project facilities. (2) All alternate feed materials were processed at the White Mesa Mill. A number of different alternate feed materials were processed during the period 2013 – 2017. The table shows the average uranium grades and the total pounds recovered from all alternate feed materials processed at the Mill during each of the years in that period. Because of the variability in uranium grades, pounds recovered is considered to be the relevant metric and tons fed is not considered to be relevant. (3) The 1,004,000 pounds recovered in 2017 include 952,000 pounds recovered for the accounts of third parties; the 172,000 pounds recovered in 2016 include nil pounds recovered for the accounts of third parties; the 229,000 pounds recovered in 2015 include 72,000 pounds recovered for the accounts of third parties; the 391,000 pounds recovered in 2014 include 85,000 pounds recovered for the accounts of third parties; and the 351,000 pounds recovered in 2013 include nil pounds recovered for the accounts of third parties. (4) Material recovered originated from several different sources that were fed to process at various times in 2015 and 2016. Therefore, the recovered amount is independent of the reported feed amount for any given period. (5) Pounds contained in tailings solutions containing previously unrecovered uranium, together with in-circuit mineralized material from previous conventional mine material processing, were recovered by processing alternate feed materials at the White Mesa Mill, though tons and grade are not available because it cannot be tied to any specific source. (6) Uranium recovery commenced at the Nichols Ranch Project on April 17, 2014. Because the Nichols Ranch Project uses ISR instead of conventional extraction methods, grade and tons of mineralized material are inapplicable to the Nichols Ranch Project. The data in the table include all uranium recovered from the Nichols Ranch Project, both before and after the Company acquired Uranerz and the Nichols Ranch Project. Of the total pounds recovered at the Nichols Ranch Project in 2015, approximately 172,000 pounds were recovered after June 18, 2015, and are for the account of the Company. (7) Figures prior to June 17, 2016 predate the Company's ownership of the Alta Mesa Project, and are therefore for the account of the previous owner. 39 Mineral Extraction The following table shows the extraction history from 2013 to December 31, 2017 from the mineral properties currently owned by the Company. Much of the material was stockpiled at the White Mesa Mill for a year or more before being processed. Since mineralized material is processed on a continuing basis during a Mill run and remains in-circuit for a considerable time mixed with all other mill feed, it is not possible to tie uranium and vanadium recovery to each project on an annual basis. Therefore, pounds of extracted uranium and vanadium are not included in this table, except for the Nichols Ranch and Alta Mesa Projects where annual extraction can be tracked. The mineral extraction table below is based on estimates of mineralized material grade as material comes out of the mine whereas the recovery table above reflects actual head grades as material is fed to process at the Mill. Therefore, the grades in the two tables differ. Project(1) 2017 2016 2015 2014 2013(1) Arizona 1(2) Pinenut(3) Nichols Ranch Alta Mesa Notes: Tons (000) --- --- --- 4 16 % U3O8 0.56% 0.58% Tons (000) --- --- 30 43 8 % U3O8 0.54% 0.55% 0.53% Pounds (000) 259 335 273(4) 200 --- Pounds (000) --- --- --- 3(5) 139(5) (1) All properties reported in this table were owned by the Company on December 31, 2017, and continue to be owned by the Company. Alta Mesa was acquired by the Company in June 2016 as part of the EFR Alta Mesa acquisition, and Nichols Ranch was acquired by the Company in June 2015 as part of the Uranerz acquisition. Properties sold or otherwise disposed of are not included in this table. Production for the US Mining Division prior to June 29, 2012 predates the Company's ownership of the US Mining Division, and was therefore for the account of the previous owner. (2) The Arizona 1 Project was placed on Standby in February 2014. (3) The Pinenut Project was placed into reclamation in August 2015 due to depletion of the identified resources. (4) Uranium recovery commenced at the Nichols Ranch Project on April 17, 2014. Of the total pounds recovered at the Nichols Ranch Project in 2015, approximately 172,000 pounds were recovered after June 18, 2015, and are for the account of the Company. (5) Production prior to June 17, 2016 predates the Company's ownership of the Alta Mesa Project, and is therefore for the account of the previous owner. Summary of Mineral Reserves and Resources John H. White, Colorado PE # 0047237, the Company’s VP of Technical Services, is responsible for the disclosure of scientific or technical information concerning mineral projects in this Annual Report. The following tables show the Company's estimate of Mineral Reserves and Mineral Resources as of December 31, 2017. NI 43-101 requires mineral companies to disclose Mineral Reserves and Mineral Resources using the subcategories of Proven Mineral Reserves, Probable Mineral Reserves, Measured Mineral Resources, Indicated Mineral Resources and Inferred Mineral Resources. Energy Fuels reports Mineral Reserves and Mineral Resources separately. Properties sold or otherwise disposed of, or committed to be sold or otherwise disposed of, during 2017 or 2018 are not included in the table. Such properties include Reno Creek and Torbyn, which are not included in the table. Except as stated below, the Mineral Reserve and Mineral Resource information shown below is as reported in the various technical reports prepared in accordance with NI 43-101 (the “Technical Reports”) by qualified persons employed by Peters Geosciences, BRS Inc., SRK Consulting (U.S.) Inc., and Roscoe Postle Associates Inc. See “Mineral Projects” below. The table below also reflects the Company’s adjustments to the resources as of December 31, 2017 at the properties where exploration and well installation drilling and/or extraction were in progress in 2017; notably at the Nichols Ranch Project. The Pinenut Project has been 40 removed from the table since extraction of all known resources was completed during 2015. An updated Technical Report for The Daneros Project was filed on March 9, 2018. The updated Mineral Resource for Daneros is given in the Mineral Resource table below. Mineral Reserve Estimates - Uranium(1)(2)(3)(4) Proven Mineral Resources Probable Mineral Reserves Tons (000) --- Grade % eU3O8 --- Pounds eU3O8 (000) --- Tons (000) 3,955 Grade % eU3O8 0.115% Pounds eU3O8 (000) 9,117 --- --- --- --- --- --- 3,498 0.132% 9,248 7,453 0.123% 18,365 Sheep Mountain - Congo Pit Sheep Mountain - Underground Total Mineral Reserves Notes: (1) The Mineral Reserve estimate in this table complies with the requirements of NI 43-101 and the classifications comply with CIM definition standards and do not represent reserves under SEC Industry Guide 7. (2) Mineral Reserves are estimated at a uranium grade x thickness (G.T.) cut-off grade of 0.10 G.T. (2 ft. of 0.05% eU3O8) for the Congo Pit and 0.45 G.T. (6 ft. of 0.075% eU3O8) for Sheep Underground. (3) Mineral Reserves are estimated using a long-term uranium price of US$65 per pound U3O8. (4) Numbers may not add due to rounding. Mineral Resource Estimates – Uranium(1)(2)(3)(4) Measured Mineral Resources Indicated Mineral Resources Inferred Mineral Resources Tons (000) Grade % eU3O8 Pounds eU3O8 (000) Tons (000) Grade % eU3O8 Pounds eU3O8 (000) Tons (000) Grade % eU3O8 Pounds eU3O8 (000) ISR Properties 1,000 2,471 0.140% 0.111% 5,500 561 0.099% 1,112 0.151% 371 1,512 0.107% 3,246 6,964 0.120% 16,794 357 123 2,281 0.061% 2,782 1,550 0.049% 1,511 190 0.037% 142 310 0.062% 387 1,198 0.130% 3,115 2,823 0.106% 6,008 4,540 13,372 24,056 Conventional Properties 6 0.43% 56 132 0.90% 2,378 18 0.38% 134 208 0.48% 1,984 1,303 0.48% 12,580 1,198 0.47 11,206 --- --- --- --- --- --- 1,009 0.18% 3,732 --- 240 --- 0.16% --- 772 6,544 11,084 41 12,895 0.12% 30,285 --- --- --- 2,410 0.27% 12,800 1,610 0.25% 8,080 132 20 201 0.14% 0.36% 367 142 185 0.10% 362 7 0.37% 52 0.28% 1,122 742 0.35% 5,248 59,674 73,047 25,082 49,138 Nichols Ranch(5) Alta Mesa(6) Reno Creek Other Power River Basin Properties(7) ISR Subtotal Canyon Roca Honda(8) Sheep Mountain(9) Henry Mountains(10) La Sal(11) Daneros Other Properties(12) Conventional Subtotal Total Mineral Resources (eU3O8) Notes: (1) The Mineral Resource estimates in this table comply with the requirements of NI 43-101 and the classifications comply with CIM definition standards and do not represent reserves under SEC Industry Guide 7. Mineral resources that are not reserves do not have demonstrated economic viability. See “Cautionary Note to U.S. Investors Concerning Disclosure of Mineral Resources,” above. (2) Mineral Resources were estimated at various %eU3O8 or G.T. cut-off grades. Details regarding cut-off grade calculations for each project are given in the project’s respective section below. (3) Mineral Resources were estimated at various long-term uranium prices. The specific long-term uranium price for each project is given in the project’s respective section below. (4) Numbers may not add due to rounding. (5) The numbers shown represent Energy Fuels share of the Nichols Ranch Project, which is less than 100% due to a portion that is held by Akose Mining Venture. The total Nichols Ranch Project Mineral Resources (100%) are shown in the Nichols Ranch section of this report, and include 1.0 million, 6.2 million, and 1.2 million pounds of measured mineral resources, indicated mineral resources, and inferred mineral resources, respectively. The Nichols Ranch Project is comprised of three properties: the Nichols Ranch Wellfield, the Hank Property and the Jane Dough Property. A portion of the Jane Dough Property is held through the Arkose Mining Venture, in which the Company has an 81% interest. The Mineral Resources shown in the table differ from those in the 2015 Nichols Ranch Technical Report due to adjustments made by the Company by subtracting recovered material (857,041 pounds) and adding additional resources discovered by drilling during well field installation (162,500 pounds). (6) Includes Alta Mesa and Mesteña Grande. (7) The other Powder River Basin ISR properties include: the North Rolling Pin Property, the West North Butte Property, the East North Butte property, the Willow Creek property, and the East Buck, Little Butte, Sand Rock and South Doughstick properties in the Arkose Joint Venture. The Mineral Resources for the Arkose properties are included in the table as 81% of the total, which is Energy Fuels share. (8) The numbers do not include the historical resource estimate for the Adjacent Roca Honda Properties. See “The Roca Honda Project,” below. (9) The Sheep Mountain Indicated Mineral Resource includes Probable Mineral Reserves calculated in accordance with NI 43-101 of 18,365,000 pounds of eU3O8 in 7,453,000 tons at a grade of 0.123%. Such mineral resources do not constitute reserves under SEC Industry Guide 7. (10) The Henry Mountains Complex includes the Tony M, Southwest, Indian Bench and Copper Bench properties. (11) The La Sal Project includes the Energy Queen, Redd Block, Beaver, and Pandora properties. (12) This includes all conventional Non-Material properties, including: Wate, EZ Project, Whirlwind, and the retained portion of Sage Plain. Mineral Resource Estimate – Vanadium(1)(2)(3)(4)(5) Measured Mineral Resources Pounds V2O5 (000) 19,596 Grade % V2O5 Tons (000) 0.97% 1,009 Indicated Mineral Resources Pounds V2O5 (000) 1,930 Grade % V2O5 Tons (000) 0.73% 132 Inferred Mineral Resources Pounds V2O5 (000) Grade % V2O5 Tons (000) 185 0.51% 1,902 240 1.32% 6,350 201 0.94% 3,797 447 0.74% 6,660 25,946 5,727 8,562 Las Sal(6) Other Properties(7) Total Mineral Resources (V2O5) Notes: (1) The Mineral Resource estimates in this table comply with the requirements of NI 43-101 and the classifications comply with CIM definition standards and do not represent reserves under SEC Industry Guide 7. Mineral resources that are not reserves do not have demonstrated economic viability. See “Cautionary Note to U.S. Investors Concerning Disclosure of Mineral Resources,” above. (2) Mineral Resources were estimated at various %U3O8 or G.T. cut-off grades. Details regarding cut-off grade calculations for each project are given in the project’s respective section below. (3) Mineral Resources were estimated at various long-term uranium prices. The specific long-term uranium price for each project is given in the project’s respective section below. (4) Various vanadium to uranium ratios were used to calculate the vanadium grades and pounds given in the table. The specific ratio used for each project is given in the project’s respective section below. (5) Numbers may not add due to rounding. (6) The La Sal Project includes the Energy Queen, Redd Block, Beaver, and Pandora properties. (7) Other Properties includes Whirlwind and the retained portion of Sage Plain. 42 Mineral Resource Estimate – Copper(1)(2)(3)(4)(5)(6) Measured Mineral Resources Indicated Mineral Resources Inferred Mineral Resources Tons (000) 6 Grade % Cu 9.29% Pounds Cu (000) 1,203 Tons (000) 94 Grade % Cu 5.70% Pounds Cu (000) 10,736 Tons (000) 5 Grade % Cu 5.90% Pounds Cu (000) 570 1,203 10,736 570 Canyon Total Mineral Resources (Cu) Notes: (1) The Mineral Resource estimate in this table complies with the requirements of NI 43-101 and the classifications comply with CIM definition standards and do not represent reserves under SEC Industry Guide 7. Mineral resources that are not reserves do not have demonstrated economic viability. See “Cautionary Note to U.S. Investors Concerning Disclosure of Mineral Resources,” above. (2) For the Main and Main-Lower zones of the Canyon Mine, a 0.36% uranium equivalent cut-off grade (% U3O8 Eq) was applied to account for both the copper and uranium mineralization. In all other zones only uranium was reported and a 0.29% U3O8 cut- off grade was applied. (The %U3O8 Eq grade term is not the same as the eU3O8 % grade term with indicates probe rather than assay data listed elsewhere in this report. For details see the Canyon Technical Report). (3) Mineral Resources are estimated using a long-term uranium price of US$60 per pound and a Copper price of US$3.50 per lb. (4) A copper to U3O8 conversion factor of 18.19 was used for converting copper grades to equivalent U3O8 grades (U3O8 Eq) for cut-off grade evaluation and reporting. (5) Numbers may not add due to rounding. (6) For Canyon, Mineral Resource tonnages of uranium and copper cannot be added as they overlap in the Main and Main-Lower Zones. 43 The Nichols Ranch Project Unless stated otherwise, the following description of the Nichols Ranch Project is derived from a technical report titled “Nichols Ranch Uranium Project, 43-101 Technical Report, Preliminary Economic Assessment” dated February 28, 2015, prepared by Douglas L. Beahm, P.E., P.G. of BRS Inc. and Paul Goranson, P.E. of the Company, in accordance with NI 43-101 (the “Nichols Ranch Technical Report”). The Nichols Ranch Technical Report includes an updated NI 43-101 mineral resource estimate and the results of a Preliminary Economic Assessment (“PEA”) for the uranium resources identified to date at the Nichols Ranch Project. Each of the authors is a “qualified person” within the meaning of NI 43-101, and Mr. Beahm is “independent” of the Company within the meaning of NI 43-101. Because the independent author of the Nichols Ranch Technical Report assumed overall responsibility for all items of the technical report, the report is therefore an independent technical report under NI 43-101. The Nichols Ranch Technical Report is available on SEDAR at www.sedar.com. The Nichols Ranch Project does not have known reserves, and is therefore considered under SEC Industry Guide 7 definitions to be exploratory in nature, despite currently ongoing uranium recovery activities. Property Description and Location The Nichols Ranch Project is the Company’s currently active ISR uranium recovery project, which it acquired in June 2015 through the acquisition of Uranerz. It is located in the Powder River Basin of northeast Wyoming. The Nichols Ranch Project includes: (i) the Nichols Ranch Plant; (ii) the Nichols Ranch Wellfield; (iii) the Jane Dough Property; and (iv) the Hank Project, which includes the planned Hank Satellite Plant and the Hank Property. The Nichols Ranch Project is an ISR project; it is not an underground or open pit project. A map of the Nichols Ranch Project, including the Nichols Ranch Plant, the Nichols Ranch Wellfield, the Jane Dough Property and the Hank Property is shown below: 44 The Nichols Ranch Project is an operating ISR facility that recovers uranium through a series of injection and recovery wells. Using groundwater fortified with oxygen and sodium bicarbonate, uranium is dissolved within a deposit. The groundwater is then collected in a series of recovery wells and pumped to the Nichols Ranch Plant. The Nichols Ranch Plant creates a yellowcake slurry that is transported by truck to the White Mesa Mill where it is dried and packaged into drums that are later shipped to a conversion facility. The original plan for the Nichols Ranch Project included the construction of an ISR processing facility and a second uranium recovery and extraction facility at the Hank Project. Our current extraction plan for the Nichols Ranch Project is now divided into three separate areas, being (i) the Nichols Ranch Wellfield, (ii) the Jane Dough Property, and (iii) the Hank Property. The Nichols Ranch Wellfield is, and the Jane Dough Property is expected to be, directly connected to the Nichols Ranch Plant via pipeline. The Hank Project is expected to consist of a uranium extraction and recovery facility that will create a loaded resin that will be trucked to the Nichols Ranch Plant for elution. The Nichols Ranch Wellfield consists of our two initial production areas, being Production Area #1 and Production Area #2. The Nichols Ranch Wellfield also includes the two deep disposal wells that are permitted and constructed for the Nichols Ranch Project. The Jane Dough Property is adjacent to the Nichols Ranch Wellfield to the south and contains certain properties that are 100% owned by Energy Fuels and other properties that are held in the Arkose Mining Venture, in which we own an 81% interest. The Jane Dough Property contains two fully licensed and permitted extraction areas. The Hank Project is 100% owned by Energy Fuels and is located approximately six miles east of the Nichols Ranch Wellfield. The Hank Satellite Plant is fully licensed and permitted to be constructed and operate as a satellite to the Nichols Ranch Plant, and the Hank Property contains two targeted extraction areas. Construction of the Nichols Ranch Plant was substantially completed in 2013, and extraction commenced in the second quarter of 2014 after final NRC inspections were completed. The Jane Dough Property described above has two fully licensed and permitted extraction areas. The Company completed construction of an elution and precipitation circuit at the Nichols Ranch Plant in early-February 2016. Yellowcake slurry is now transported from the Nichols Ranch Plant to the White Mesa Mill for drying and packaging. However, the 45 Nichols Ranch Plant is currently licensed to allow for the construction and operation of a drying and packaging circuit should conditions warrant. The Nichols Ranch Project does not have known reserves under SEC Industry Guide 7, and is therefore considered under SEC Industry Guide 7 definitions to be “exploratory” in nature. During 2017, a total of approximately 259,000 pounds of U3O8 were recovered from the Nichols Ranch Project and nil pounds of mineralized material were added through drilling. Accessibility, Local Resources, Physiography and Infrastructure The Nichols Ranch Project site is located approximately 50 road miles southwest of Gillette, Wyoming and 76 road miles northeast of Casper, Wyoming in portions of Campbell and Johnson Counties, Wyoming in the Townships 41 to 45 North and Ranges 73 to 77 West. It is accessed from State Highway 50 from the east or State Highway 387 from the south, and various internal gravel-surface county and private roads. Casper is on Interstate 25, approximately one hour by air from either Denver, Colorado or Salt Lake City, Utah. The Nichols Ranch Project is accessible via two-wheel drive vehicle on existing county and/or private gravel and dirt roads. The Nichols Ranch Project is located within the Wyoming Basin physiographic province in the central portion of the Powder River Basin, within the Pumpkin Buttes Mining District. The Pumpkin Buttes are a series of small buttes rising several hundred feet above the surrounding plains. Portions of the Powder River Basin properties are located east, west and south of these buttes. The cap rocks on top of the buttes are erosional remnants of the Tertiary White River Formation that is believed to have overlain the majority of the Powder River Basin. The volcanic tuffs in the White River Formation have been cited as a source of uranium in this basin. The area in which the Powder River Basin properties is located is a low lying plain, and elevations range from approximately 4,390 feet (1,440 meters) in the northwest to approximately 5,450 feet (1,790 meters) in the southeast. Historically and currently, the land is used for livestock and wildlife grazing. Vegetation is characteristically sagebrush grassland with some pines on elevated terrain and some deciduous trees within drainages. The climate is semi-arid and receives an annual precipitation of approximately 9.4 inches, the most falling in the form of late autumnal to early spring snows. The summer months are usually hot, dry and clear except for infrequent heavy rains. Cold, wind and snow/ blizzards can make winter exploration work in this area difficult but not impossible. The weather may limit the time periods for capital construction but should not have any significant adverse impacts on the operation of an ISR facility. Infrastructure at the site of the Nichols Ranch Project is dominantly related to local oil, gas, and coal bed methane exploration and development. Mineralized locations could affect future siting of wellfields and processing facilities. Generally, the proximity of the Nichols Ranch Project to paved roads is beneficial with respect to transportation of equipment, supplies, personnel and product to and from the property. Power transmission lines are located on or near parts of the property. We have secured power from the local electrical service provider to accommodate our needs. Water is available from wells developed at planned facility locations, and water for ISR operations comes from the operation itself, i.e. the extracted groundwater. Therefore, the basic infrastructure (power, water and transportation) that is required to support an ISR mining operation is located within reasonable proximity to the Nichols Ranch Project. Ownership Our property interests vary widely, and include unpatented mining claims, private and state leasehold interests and surface use rights. Some agreements renew annually, some renew automatically when mineral extraction has commenced, and some are agreements for fixed terms. For the property agreements that expire in 2018, the Company may negotiate new agreements for only those acres that are within permit boundaries or critical project areas. Leases outside of such desired project areas may be allowed to expire, although the Company may seek to negotiate new agreements for those dropped properties in the future should market conditions warrant. We do not expect that the expiry of any property interests in 2018 and beyond, nor the forfeiture of any unpatented mining claims in 2018, will have a material effect on our ability to continue exploration and extraction activities on our properties. Our unpatented lode mining claims are located on minerals owned by the federal government and open to location, with the surface being owned by either the federal government or private individuals. In addition, the unpatented lode mining claims are recorded in the appropriate county and filed with the state office of the BLM. The unpatented lode claims do not have an expiration date. However, affidavits must be filed annually with the BLM and respective county recorder’s offices in order to maintain the claims’ validity. All of the unpatented lode mining claims have annual filing requirements ($155 per claim) with the BLM, to be paid on or before September 1 of each year. Most of the above-mentioned unpatented lode mining claims are located on Stock Raising Homestead land where the United States government has issued a patent for the surface to an individual and reserved the minerals to the United States government subject to the location rights by claimants as set forth in the federal Mining Act of 1872. Our leasehold interests are subject to the various terms as set forth in the applicable leases. The state leases and leases on fee mineral lands usually have annual payments, royalty obligations, and the terms of the leases vary, but for the most part can be extended by 46 production (as defined in the leases). The fee surface and mineral leases apply only to uranium and other fissionable minerals and typically have a 10-year term with the right to extend the leases with production (as defined in the leases). Commingling of extraction from adjacent lands is allowable under the fee mineral leases. Surface rights under applicable laws allow for exploration disturbance, road construction and facility siting. The claimant must first notify the surface owner of its intention to locate unpatented lode mining claims on the owner’s surface and then reach an agreement with the surface owner to pay for damages caused by the claimant’s operations. If an agreement cannot be reached, the claimant may post a bond with the BLM to cover the amount of the damages caused by the claimant’s operations. We have negotiated surface use agreements with various surface owners that provide us with all required surface access for the Nichols Ranch Project. The surface use agreements typically provide for reimbursement to the surface owner of actual damages resulting from our operations. Nichols Ranch Plant – 100% Energy Fuels The Nichols Ranch Plant is located on the Nichols Ranch Project property pursuant to the surface use agreements described below. Nichols Ranch Wellfield – 100% Energy Fuels The Nichols Ranch Project, which includes the Nichols Ranch Plant and the Nichols Ranch Wellfield mining permit area, consists of 36 unpatented lode mining claims, two fee surface and mineral leases, and one surface use agreement encompassing approximately 920 acres. The Nichols Ranch Wellfield permit boundary encompasses approximately 1,120 acres. There is an overriding royalty interest in favor of Excalibur Industries on all federal unpatented lode mining claims that were acquired from Excalibur Industries, defined as a gross royalty of six percent when the spot price of uranium is less than $45.00 per pound and of eight percent if the uranium spot price is $45.00 per pound or higher. In addition, there is a portion of the Nichols Ranch Wellfield that includes private (fee) mineral that is subject to the above Excalibur Industries royalty, plus an additional royalty payable to the fee mineral owner under the fee leases. Cumulatively, the combined royalties range from 12 percent to 16 percent, depending upon the price of uranium). The Company has entered into an agreement to acquire these Excalibur Industries royalties, which it intends to cancel upon acquisition. See General Development of the Business: 2017 Corporate Developments. The primary term of the leases would have expired in 2017; however, they are held by production (as defined in the leases). The primary term of the surface use agreement would have expired in 2016, however the term has been held by production. Hank Property – 100% Energy Fuels At the Hank Project, for which the Company has received a license to construct and operate a satellite plant to the Nichols Ranch Plant (known as the Hank Satellite Plant), we have 66 unpatented lode mining claims, two fee surface and mineral leases, which are not significant, and one surface use agreement encompassing approximately 1,393 acres. The Hank Project permit boundary encompasses approximately 2,250 acres. Of the 66 unpatented lode mining claims comprising the Hank Project, 56 of the claims have a royalty interest burden, payable to Excalibur Industries, of 6 or 8 percent depending on the price of uranium. This royalty interest is based on uranium produced from these claims. As mentioned above, the Company has entered into an agreement to acquire these Excalibur Industries royalties, which it intends to cancel upon acquisition. See General Development of the Business: 2017 Corporate Developments. The primary term of the leases would have expired in 2016, however they have been held beyond the primary term by production (as defined in the leases). In 2017, the Company renewed all of these leases through 2026. Jane Dough Property (Jane Dough/Doughstick – 100% Energy Fuels; North Jane and S. Doughstick – 100% Arkose Mining Venture, held 81% by Energy Fuels) In 2017, the Company received its license amendment from the NRC, which includes the Jane Dough Property in the Nichols Ranch Project permit area, and combines the Jane Dough/Doughstick, North Jane and S. Doughstick properties consisting of 115 unpatented lode mining claims, 16 mineral leases, and three surface use agreements encompassing approximately 3,121 acres. Our operating interest in the Jane Dough Property includes Energy Fuels’ 100% owned property and 81% from the two properties held by the Arkose Mining Venture. The Jane Dough Property permit amendment encompasses approximately 3,680 acres. The fee land in the project is covered by mineral leases some of which have annual payments and some of which are five year paid up leases. The mineral leases have primary terms of ten years and can be held by ongoing uranium extraction (as defined in the leases). Some of the leases expire in 2018, and 2019. The fee surface is covered by three separate surface use agreements, which include damage payments paid on an annual basis. The mining leases have a variety of royalty payments based on a fixed rate, a two tier system, or a sliding scale system. One of the leases has a fixed royalty rate of 4% of the gross proceeds. Two of the leases have a two-tier royalty based on the price of U3O8 at the time of the sale, and they are 6% for a U3O8 price less than $75 per pound, and 8% for a U3O8 price equal to or greater than $75 per pound. Five of the leases have a sliding scale royalty that runs from a low of 2% at a U3O8 price of $25 per pound up to a high of 10% for a U3O8 price of equal to or greater than $100 per pound. Four leases have a sliding scale royalty that runs from a low of 4.0% at a U3O8 price of $40 per pound up to a high of 10% for a U3O8 price of equal to or greater than $100 per pound. Four of the leases have a sliding scale royalty that runs from a low of 4.5% at a U3O8 price of $49.99 up to a high of 10% for a U3O8 price of equal to or greater than $100 per pound. There is an overriding royalty interest held by Excalibur Industries that covers some of the unpatented claims located in Sections 20, 21, 28 and 29, Township 43 North, Range 76 West, which is a two-tiered royalty based on quarterly 47 production of U3O8 and adjusted annually by the actual amount of U3O8 sold during the previous year. The Excalibur royalty amounts are based on the average quarterly spot price for U3O8, and they are 6% for a U3O8 price equal to or less than $45 per pound and 8% for a U3O8 price greater than $45 per pound. As mentioned above, the Company has entered into an agreement to acquire these Excalibur Industries royalties, which it intends to cancel upon acquisition. See General Development of the Business: 2017 Corporate Developments. There are twenty (20) unpatented mining claims located in Section 32, Township 43 North, Range 76 West that have an overriding royalty interest of 0.25%. This overriding royalty interest is based on production of uranium on said claims. Two of the surface use agreements have a two tiered royalty based on the sales price of the U3O8 received by Uranerz, and they are 1% for a sales price of less than $50 per pound; and 2% for a sales price of equal to or greater than $50 per pound. Uranium Severance Tax We are required to pay a standard uranium industry severance tax of approximately 4% of sales and an ad valorem tax (annual property tax based on assessed values) to the State of Wyoming, in addition to various maintenance, land impact and access fees and other consideration to surface owners. Permitting and Licensing Energy Fuels has received all regulatory approvals necessary to conduct extraction and uranium processing activities at the Nichols Ranch Plant and Nichols Ranch Wellfield. In December 2010, Uranerz received its Permit to Mine for the Nichols Ranch Project from the Wyoming Department of Environmental Quality (“WDEQ”) - Land Quality Division (“WDEQ-LQD”). In July 2011, Uranerz received a Source Material License from the NRC for the Nichols Ranch Plant and Nichols Ranch Wellfield, and construction of the Nichols Ranch Plant immediately began. Both the state and federal agencies analyzed all environmental aspects of the Nichols Ranch Project including reclamation of the land surface following extraction operations and restoration of impacted ground water. Workplace safety and the safety of the public are also closely monitored by regulatory agencies. We have posted a reclamation bond with the regulatory agencies in an amount of $6.8 million to cover the total estimated cost of reclamation by a third party as a requirement of the licenses. The various state and federal permits and licenses that were required and have been obtained for the Nichols Ranch Project, exclusive of the expansion to the Jane Dough Property, are summarized below: Primary Permits and Licenses for the Nichols Ranch Project (Nichols Ranch and Hank Units Only) Permit, License, or Approval Name Agency Source Material License NRC Permit to Mine (UIC Permit) WDEQ-LQD Aquifer Exemption WDEQ-LQD; EPA Permit to Appropriate Groundwater SEO Wellfield Authorization WDEQ-LQD Deep Disposal Well Permits WDEQ-WQD WYPDES WDEQ- WQD Plan of Operations (Hank Unit only) BLM Air Quality Permit WDEQ-AQD Status Obtained Obtained Obtained Obtained Obtained Obtained Obtained Obtained Obtained Notes: NRC - Nuclear Regulatory Commission EPA – Environmental Protection Agency WDEQ-LQD - Wyoming Department of Environmental Quality Land Quality Division WDEQ-WQD - Wyoming Department of Environmental Quality Water Quality Division WDEQ-AQD - Wyoming Department of Environmental Quality Air Quality Division WYPDES – Wyoming Pollutant Discharge Elimination System SEO - State Engineer's Office 48 Under the licensed plan, the Nichols Ranch Plant has been built, and a satellite processing facility is licensed for the Hank Project. In 2017, the NRC approved a source material license amendment to add the Jane Dough Property to the existing license for the Nichols Ranch Project, and the Wyoming Department of Environmental Quality approved an amendment to our Permit to Mine to incorporate the Jane Dough Property. The Jane Dough Property is now fully licensed and permitted as part of the Nichols Ranch Project. The Jane Dough Property is adjacent to the Nichols Ranch Wellfield and is expected to share its infrastructure. We are now able to bring the Jane Dough Property into extraction operations before the Hank Project. Due to its close proximity, extracted solutions from the Jane Dough Property may be delivered directly to our Nichols Ranch Plant by pipeline, thus eliminating the need for a larger capital outlay to construct a satellite plant as is planned for the Hank Project. Our Jane Dough Property includes the Doughstick, South Doughstick and North Jane properties. Additional wellfields may be added to the extraction operations plan as we continue to assess geological data. Geology The Nichols Ranch Project is located in the Powder River Basin. The mineralized trends within the Nichols Ranch Project are alteration- reduction trends hosted in the Eocene age channel sands that lie at depths of approximately 300 to 1,100 feet from the surface. Roll front deposits of uranium bearing material are anticipated to occur within these properties. An alteration-reduction trend is a natural chemical boundary trend line in a sandstone aquifer where reduced (non-oxidized) sand is in contact with altered (oxidized) sand. Uranium mineralization may be found along the trend line. The properties in the Nichols Ranch Project contain alteration-reduction trends hosted in Eocene age channel sands. Alteration-reduction trends in the Pumpkin Buttes Mining District are typically composed of multiple, stacked roll front deposits that often contain associated uranium mineralization. A stacked roll front is a type of uranium occurrence found in thick sandstone where a number of mineralization trends are stacked on top of each other. Uranium mineralization within and adjacent to the Nichols Ranch Project are found in the Eocene Wasatch Formation (“Wasatch”). The Wasatch is a fluvial deposit composed of arkosic sandstones that are typically 25% or more feldspar grains and indicates a source rock where chemical weathering was not extreme and the sediments have not been transported far. A fluvial deposit is a deposit of uranium mineralization found in sandstones that originated from sediments laid down by streams and rivers. The arkosic sandstone is a type of sandstone that contains a high percentage of feldspar grains. The medium grain size and relatively good sorting of this sediment implies water transportation, probably in a meandering river/stream system. The Wasatch Formation is interlaid with sandstones, claystones, siltstones, carbonaceous shale, and thin coal seams that overlie the Paleocene Fort Union Formation, another fluvial sedimentary unit. History The Nichols Ranch Project is located within the Pumpkin Buttes Mining District, which was the first commercial uranium extraction district in Wyoming. Uranium was first discovered in the Pumpkin Buttes in 1951. Intermittent uranium extraction from about 55 small mines occurred through 1967 producing 36,737 tons of material containing 208,143 pounds of uranium. This early mining activity focused on shallow oxidized deposits exploited by small open pit mines. The material was generally transported to the Atomic Energy Commission (“AEC”) buying station in Edgemont, South Dakota. Modern mining in the district has focused on deeper reduced deposits, including facilities operated by Cameco Corporation and Uranium One Inc. The properties included in the Nichols Ranch Project were originally part of a large exploration area encompassing Townships 33 through 50 North of Ranges 69 through 79 West, on the 6th principal meridian. In 1966, Mountain West Mines Inc. (“MWM,” now known as Excalibur Industries) began a successful drilling exploration program in a portion of this area. In 1967, MWM entered into an agreement with Cleveland-Cliffs Iron Company (“CCI”) for further exploration and an option if suitable resources were found. CCI exercised its option in 1976 with plans to begin underground mining operations in the vicinity of North Butte. Changing economic conditions and the introduction of ISR mining technology reportedly ended much of CCI’s interest in the area. By the late 1980’s, CCI began selling select properties or allowing them to revert to the federal government. Between 1968 and 1980, CCI drilled 117 holes and installed 3 water wells on the Nichols Ranch Project area. Texas Eastern Nuclear Inc. in 1985 completed limited drilling and exploration on the property (approximately 28 borings) and in early 1990s Kerr McGee Corporation and Rio Algom Mining Corporation also completed limited drilling in the area. Mineralization The targeted mineralized zones for the Nichols Ranch Wellfield in the A Sand unit are 300 to 700 feet below the surface and occur in two long narrow trends meeting at the nose. The nose is in the northwest corner of the deposit where the two narrow trends meet to form the tip of the geochemical front. The Hank Project’s two targeted mineralized zones in the F Sand unit range from 200 to 600 feet below the ground surface depending on the topography and changes in the formation elevation and stratigraphic horizon. The targeted 49 mineralization zone for the Jane Dough Property is the A Sand unit, the same as Nichols Ranch, at depths of 300 to 750 feet below the surface. Mineral Resource Estimates BRS prepared an updated NI 43-101 compliant Mineral Resource estimate for the Nichols Ranch Project in the Nichols Ranch Technical Report. The updated Mineral Resource estimate is effective as at January 1, 2015 and is summarized in the table below. Mineral Resources were estimated using the GT Contour method. The primary data used in evaluation are equivalent uranium values as quantified by downhole geophysical logging reported as %e U3O8. Radiometric equilibrium was evaluated and a disequilibrium factor ("DEF") of 1 was used. The minimum uranium grade included in the estimate was 0.02% eU3O8. A minimum grade of 0.02% U3O8 and GT (grade x thickness) of 0.20 were used in these resource calculations. Mineral resources are reported at a cutoff of 0.20 GT, which is the cutoff applied at the Nichols Ranch Project. The table below provides a summary of Mineral Resources by classification following CIM guidelines. There are no Mineral Reserves on the property at this time. BRS noted that it is not aware of any known environmental, permitting, legal, title, taxation, socioeconomic, marketing, political, or other relevant factors that could materially affect the current resource estimate. Nichols Ranch Remaining Mineral Resources – Uranium(1)(2)(3)(4)(5) Classification Property Tons (000) Grade % eU3O8 Pounds eU3O8 (000) Energy Fuels Pounds (000)(6) Nichols Ranch Measured Resources (M) Nichols Ranch 357 0.140% 1,000 Nichols Ranch 428 0.126% 1,079 Hank 450 0.095% 855 Nichols Ranch Indicated Resources (I) Jane Dough 1,892 0.112% 4,237 Nichols Ranch Total (M & I) Nichols Ranch Hank Nichols Ranch Inferred Resources Jane Dough Nichols Ranch Inferred Total Notes: 3,127 0.115% --- --- 7,171 --- 423 170 593 0.095 803 0.112 381 0.100% 1,184 1,000 1,079 855 3,567 6,501 --- 803 309 1,112 (1) The Mineral Resource estimate in this table complies with the requirements of NI 43-101 and the classifications comply with CIM definition standards and do not represent reserves under SEC Industry Guide 7. Mineral resources that are not reserves do not have demonstrated economic viability. See “Cautionary Note to U.S. Investors Concerning Disclosure of Mineral Resources,” above. (2) Remaining Mineral Resource includes reduction for production of 857,041 pounds from January 1, 2015 through January 1, 2018, and an increase of approximately 162,500 pounds due to additional drilling. (3) Mineral Resources are estimated at a uranium grade x thickness (G.T.) cut-off grade of 0.20 G.T. (minimum 0.02% eU3O8). (4) Mineral Resources are estimated using a long-term uranium price of US$65 per pound. (5) Numbers may not add due to rounding. (6) “Energy Fuels Pounds” represent 100% of Nichols Ranch and Hank, and 81% of the Company's share of the portion of Jane Dough held by the Arkose Mining Venture. 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. Activities Subsequent to Nichols Ranch Technical Report Subsequent to the completion of the Nichols Ranch Technical Report, the Company has continued to operate and advance the Nichols Ranch Project, as described below. The information contained in this subsection entitled “Activities Subsequent to Nichols Ranch 50 Technical Report”, was prepared by the Company and has not been reviewed or confirmed by the authors of the Nichols Ranch Technical Report. Wellfield Development and Exploration Completed by Energy Fuels Prior to its acquisition by Energy Fuels in June 2015, Uranerz drilled 257 exploration holes, including three core holes and three water wells at the Nichols Ranch Project during 2006 and 2007 and 25 exploration holes and seven wells in 2009. In addition, Uranerz drilled 61 exploratory holes and seven wells within the Hank Property during 2006 and 2007 and eight additional wells in 2009. There has been no new drilling activity at the Hank Project since 2009. Uranerz drilled 691 exploration holes and 29 wells for baseline monitoring at the Jane Dough Property. There has been no new drilling at the Jane Dough Property since 2010. Uranerz drilled a total of 78 rotary drill holes on the Hank Property, Nichols Ranch Wellfield, and Jane Dough Property during 2006, with 46 holes demonstrating uranium mineralization. During 2006, environmental permitting activities also continued at the Hank Property and Nichols Ranch Wellfields with the completion of a total of five hydrogeologic test wells, and the drilling of six core holes. The core was submitted for laboratory testing to support permitting requirements as well as to define resource disequilibrium attributes. From February 19 to December 20, 2007, Uranerz drilled a total of 486 uranium trend delineation holes and eight hydrologic sampling wells on the Nichols Ranch Project, utilizing as many as three drill rigs and one electric log probing unit. This represents a total of approximately 300,000 feet of drilling with an average depth of 617 feet per hole. A total of 214 delineation holes were drilled on Nichols Ranch in 2007. In the final months of the 2007 drilling program, exploration efforts focused on the Hank Property and Nichols Ranch Wellfield to facilitate sub-surface geologic mapping with cross sections and to refine previous geologic models delineating known trends of uranium mineralization. During 2008, no new exploration work was undertaken at the Nichols Ranch Wellfield. During 2009, 51 delineation holes were drilled at the Nichols Ranch Wellfield, including the Doughstick and North Nichols Ranch properties. The purpose of this drilling was primarily to prepare for the installation of baseline monitor wells for the planned Nichols Ranch Plant. Additional drilling was carried out on the Doughstick properties. During 2011, 38 delineation holes were drilled in 2011 on the Nichols Ranch Wellfield. The purpose of this drilling was for final delineation drilling prior to beginning the monitor well and extraction well installation in Production Area #1 of the Nichols Ranch Wellfield. During 2012, Uranerz engaged in drilling exploration efforts and wellfield installation at Production Area #1 at the Nichols Ranch Wellfield. At Production Area #1, 263 extraction wells were cased and cemented. The extraction wells were connected to header houses with buried feeder lines. It was planned that initial extraction should begin with four header houses. Three header houses were set on their foundations in 2012 and connected to individual extraction wells. The Uranerz 2013 and 2014 drilling programs at the Nichols Ranch Wellfield were restricted to adding extraction and monitor wells. No new exploration drilling was conducted. During 2015, Uranerz engaged in drilling delineation efforts and wellfield installation at Production Area #1 of the Nichols Ranch Wellfield, where 283 extraction wells were cased and cemented. At Production Area #2 of the Nichols Ranch Wellfield, 51 monitor wells were cased and cemented. The extraction wells were connected to header houses with buried feeder lines. Initial extraction at the Nichols Ranch Wellfield began with four header houses. In 2015, two additional header houses (#5 and #6) were set on their foundations and connected to the individual extraction wells. In 2016, the Company completed drilling 12 delineation holes and drilling and casing of 86 extraction wells in Header Houses #7 and #8 in Production Area #1. Header House #7 was turned on in March of 2016 and Header House #8 was turned on in June of 2016. In Production Area #2, 133 extraction and injection wells were drilled and cased. Header House #9 was completed and turned on in March of 2017. No drilling or other development activities were performed in 2017 or to date in 2018. Current Status of Wellfields All the currently planned and permitted wellfields are in Production Areas #1 and #2 of the Nichols Ranch Wellfield. The Nichols Ranch Wellfield is expected to have a total of 13 header-houses, with Production Area #1 comprising header-houses 1 through 8, and Production Area #2 comprising header-houses 9 through 13. Each of the two planned Nichols Ranch Wellfield Production Areas will 51 include a number of injection wells, recovery wells, monitoring wells, header houses and associated piping and power supply. Header houses will be located within the Production Areas and will distribute recovered fluids from recovery wells to trunk lines, and injection fluids from the processing facility through the trunk lines to injection wells. See the map below illustrating Production Areas #1 & #2, and the plant. 52 We are currently engaged in uranium recovery activities in Production Area #1 and, as the productivity or solution grade (uranium concentration in the recovered ground water) of some installed patterns decreases below the economic limit, replacement patterns will be placed into operation in order to maintain the desired flow rate and solution grade at the processing plant. As patterns reach their economic limit and extraction flows cease, restoration activities will commence in these areas. The first five header houses and their respective wellfields in Production Area #1 at the Nichols Ranch Wellfield were installed and extracting uranium at the time we acquired Uranerz in June 2015. Header house #6 was turned on in November 2015. We placed our 7th and 8th header-houses on-line in March and July 2016, respectively, thereby completing development of Production Area #1. In February, 2017 we completed construction on our 9th header-house, marking the beginning of development in Production Area #2. Uranium recovery operations from Production Area #2 commenced in March of 2017. Nichols Ranch Plant In 2014, construction of the Nichols Ranch Plant was completed. The Nichols Ranch Plant is licensed to produce up to two million pounds of uranium per year through three major processing solution circuits: (i) a recovery and extraction circuit; (ii) an elution circuit; and (iii) a yellowcake production circuit. The Nichols Ranch Plant is currently constructed and operated with the recovery and extraction circuit and the elution circuit installed. We retain the ability to construct and operate a yellowcake drying and packaging circuit at the Nichols Ranch Plant at a later date if desired. The Nichols Ranch Plant is currently engaged in uranium recovery operations and is processing uranium-bearing wellfield solutions from Production Areas #1 and #2 of the Nichols Ranch Wellfield. At the current time, yellowcake production is occurring at the White Mesa Mill, whereby yellowcake slurry is shipped by truck from the Nichols Ranch Project to the Mill where it is dried and packaged in drums as uranium concentrate product. Prior to the completion of the elution circuit in February 2016, loaded resin was transported by truck to a third party facility for elution, drying and packaging, under a toll processing arrangement. The Nichols Ranch Plant was acquired by the Company on June 18, 2015, through the acquisition of Uranerz. As of December 31, 2017, the total cost attributable to the Nichols Ranch Plant on the Company’s financial statements was $29.21 million. The Company’s Planned Work Header House #9 was completed and uranium extraction began in March 2017. The addition of this header house brought another 123 extraction and injection wells online. As a result of our recent NRC and WEQ license and permit amendment approvals, we are now able to expand extraction operations to the Jane Dough Property before expanding to the Hank Project. The Hank Project, including the permitted but not constructed Hank Satellite Plant and planned Hank wellfield, is currently licensed as a satellite uranium extraction and recovery facility, with loaded resin from the satellite facility, when constructed, expected to be transported by truck to the Nichols Ranch Plant for elution. Construction activities at the Hank Project will not commence until market conditions warrant. In the future, we will consider whether to amend our current license for the Hank Project to include a pipeline to our Nichols Ranch Plant, which would replace or eliminate the currently permitted satellite ion exchange recovery facility. If market conditions warrant construction activities at the Hank Project, our extraction plan for the Hank Property will likewise target two planned extraction areas. Should market conditions warrant, the Jane Dough and Hank Properties would be expected to follow a similar construction, extraction, and restoration schedule as outlined above for the Nichols Ranch Wellfield extraction areas. 53 The Alta Mesa Project Unless stated otherwise, the following description of the Alta Mesa Project is derived from a technical report titled, “Alta Mesa Uranium Project, Alta Mesa and Mesteña Grande Mineral Resources and Exploration Target, Technical Report National Instrument 43-101” dated July 19, 2016, prepared by Mr. Douglas Beahm, P.E., P.G. of BRS Inc. in accordance with NI 43-101 (the “Alta Mesa Technical Report”). The author is a “qualified person” within the meaning of NI 43-101, and because the sole author is “independent” of the Company within the meaning of NI 43-101 the report is therefore considered an independent technical report under NI 43-101. The Alta Mesa Technical Report is available on SEDAR at www.sedar.com. The Alta Mesa Project does not have any known reserves, and is therefore considered under SEC Industry Guide 7 definitions to be exploratory in nature, despite its history of uranium recovery activities. No current preliminary economic assessment, pre-feasibility study or feasibility study has been completed. 54 Property Description and Location The Alta Mesa Project is a fully-licensed ISR uranium recovery facility that the Company acquired in June 2016 through the acquisition of EFR Alta Mesa LLC (previously named Mesteña Uranium LLC). It is located in South Texas and is currently on standby. The Alta Mesa Project is not an underground or open pit project. The Alta Mesa central processing facility and mine office is located at 755 CR 315, Encino, Texas 78353, in Brooks County, Texas, at approximately 26° 54’ 08” North Longitude and 98° 18’ 54” West Latitude. The site is located approximately 11 miles west of the intersection of US 281 and Ranch Road 755, which is 22 miles south of Falfurrias, Texas. The Project is located within a portion of the private land holdings of the Jones Ranch, founded in 1897. The ranch comprises approximately 380,000 acres. The ranch holdings include surface and mineral rights including oil and gas and other minerals including uranium. Active uses of the lands in addition to uranium exploration and production activities include agricultural use (cattle), oil and gas development, and private hunting. The Project consists of Uranium Mining Leases for uranium ISR mining (4,598 acres) and Mineral Options (195,501 acres) comprising some 200,100 total acres. The Project is defined as constituting two distinct project areas with sufficient drilling to define resources. These two areas are subdivided, as listed below and illustrated on the map on the following page: • The Alta Mesa project area, Brooks County, Texas, comprising 16,010 acres, including, The Alta Mesa mine area and central processing facility South Alta Mesa Indigo Snake • The Mesteña Grande project area, Jim Hogg County, Texas, comprising 47,088 acres, including, Mesteña Grande Goliad Mesteña Grande North Mesteña Grande Central Mesteña Grande Alta Vista El Sordo The remaining 137,002 acres lack sufficient exploration drilling to define any resources at this time. Accessibility, Local Resources, Physiography and Infrastructure The Project is located primarily in Brooks and Jim Hogg counties, Texas, with the central processing facility in Brooks County. Brooks County is generally rural and according to the 2010 United States Census, there were 7,223 people living in the county. The population density was 8 people per square mile. Most of the workers for the operation are from the local area and nearby communities such as Kingsville, Texas approximately 40 miles from the site. Some staff members commute from Corpus Christi, Texas approximately 90 miles from the site. The Project is located in the coastal plain of the Gulf of Mexico. Topography of the lower Gulf Coast is relatively flat, whereas the upper Gulf Coast, including most of the current and past mining operations of the South Texas Uranium Province, generally has low relief, rolling plains, except where it is locally dissected by rivers and streams. Elevations range from sea level to about 800 ft. in the southwest. Three major rivers from south to north are: the Nueces River, which flows into Corpus Christi Bay, and the San Antonio and Guadalupe Rivers, which flow into San Antonio Bay southeast of the city of Victoria. The Project is accessible year round. The site is located approximately 11 miles west of the intersection of US Highway 281 (paved) and Ranch Road 755 (paved), 22 miles south of Falfurrias, Texas. Commercial airlines serve both San Antonio and Corpus Christi. Many of the local communities have small airfields and there are numerous private airfields in the region. Overall the climate is warm and dry, with hot summers and relatively mild winters. However, the region is strongly influenced by its proximity to the Gulf of Mexico and, as a result, has a much more marine-type climate than the rest of Texas, which is more typically continental. Monthly mean temperatures in the region range from 55oF in January to 96oF in August. The area rarely experiences freezing conditions and, as a result, the majority of the processing facility and infrastructure is located outdoors. Wellfield piping and distribution lines do not require burial for frost protection. Annual precipitation ranges from 20 to 35 inches regionally. Primary risk for severe weather is related to heavy thunderstorms and potentially effects of hurricanes in the Gulf Coast. 55 Local infrastructure includes electricity service, which is adequate for mine and mineral processing activities. The Alta Mesa facility also has telephone and internet service in the form of a T-1 fiber optics line. The plant has an automated control and monitoring system, which allows remote monitoring of the facility, and includes fail safe systems, which can shut down portions of the system in the event of an upset condition. The facility is fully secured with on-site and remote monitoring. Water supply for the Project is from established and permitted local wells. Liquid waste from the processing facility is disposed of via deep well injection through two permitted Underground Injection Control (UIC) Class I disposal wells. Solid waste from the processing facilities is disposed of off-site at licensed disposal facilities. No tailings or other related waste disposal facilities are needed. The Project is located on an operating cattle ranch. In addition, there is significant local oil and gas development and production. The Alta Mesa area was first developed as an oilfield in the 1930s with production ongoing, primarily for natural gas. Other land uses include farming and recreational uses such as hunting. 56 - 1 '' '' ''' ''' '' '' ' ,_ ) -·___ _ ]____ ____ ____ ___ BROOKS CO. _ll!U..S co. ....!. '"',,, ', '--7' ......---------' .............---'"'.... .......... ......._ ,' -------- MESTENA GRANDE 1 ----------- i ALTA VISTA I.:. ""'>------ '' '' '' '' ' ' ''' '' '' '' ''' )'' ' ,/ f I' :/ : ( INDIGO SNAKE SEE FIGURE 14.1 FOR ----------i AREA NAMES IN THIS AREA --- !,TO INTERSTATE 69C ---... _ .................., Sl H MESA /,.,---- , ...... I / ,/ -(, ,, _ _ _ _ _ _ _ _J _!lG O:..j _ BROOKS CO. STARR cO: 7 HIDALGO co:- _ _ _ _ _ ', / / •••-------· I ',·•••,,,\ 17.. '---------- I/ --------..... ...........-----------------------------------,,,,-,'-,' ,7 ·-·-:,,':, / Ill I LEGEND PROPERTY BOUNDARY COUNTY LINE EXISTING ROAD AREA BOUNDARY eF PREPARED FOR ENERGY FUELS INC, PREPARED BY BR 5 INCORPORATED 1130 Major A u•, Rl...rton, WY 82501 ALTA MESA URANIUM PROJECT BROOKS AND JIM HOGG COUNTIES, TEXAS, USA llESTERA GRANDE PROJECT AREA ---- 0 " -JSJlS' l\'£RTY KAP, BROOKS AND llll HOGG COUNTIES GRAPHIC SCALE ALTA llESA PROJECT AREA 1 "ti' ::::11c : • :::J• • l i '=:::j1' I Inch = 4 miles DRA'llllN BY: COS RE\1SION NO. DATE BY DATE: 5/20/14 QtECKED BY:DlB LAST PLOT DATE: 5/23/1 DRAWING SCALE: 1"•4 Mll£S flGURE: 4.1 57 The area is regionally classified as a coastal sand plain. Brooks County comprises 942 square miles of brushy mesquite land. The nearly level to undulating soils are poorly drained, dark and loamy or sandy; isolated dunes are found. In the northeast corner of the county the soils are light-colored and loamy at the surface and clayey beneath. The mineral leases and options described below include provisions for reasonable use of the land surface for the purposes of ISR mining and mineral processing. Alta Mesa is a fully licensed, operable facility with sufficient sources of power, water, and waste disposal facilities for operations and aquifer restoration. While the current staff level has been reduced, sufficient local personnel are available for mine operations. Ownership Mineral ownership in Texas is a private estate. Private title to all land in Texas emanates from a grant by the sovereign of the soil (successively, Spain, Mexico, the Republic of Texas, and the state of Texas). By a provision of the Texas Constitution the state released to the owner of the soil all mines and mineral substances therein. Under the Relinquishment Act of 1919, as subsequently amended, the surface owner is made the agent of the state for the leasing of such lands, and both the surface owner and the state receive a fractional interest in the proceeds of the leasing and production of minerals. The Project consists of a private Uranium Solution Mining Lease (4,598 acres) and Options (195,501 acres) for uranium comprising some 200,100 total acres consisting of acreage associated with currently approved mining permits issued by the Texas Commission on Environmental Quality and 9 prospect areas. The Uranium Solution Mining Lease, originally dated June 1, 2004, covers 4,575 acres, more or less, out of the “La Mesteñas” Ysidro Garcia Survey, A-218, Brooks County, Texas and “Las Mesteñas Y Gonzalena” Rafael Garcia Salinas Survey, A-480, Brooks County, Texas (description corrected in a later amendment). This original Uranium Solution Mining Lease has been superseded by the Amended and Restated Uranium Solution Mining Lease dated June 16, 2016, as part of the share purchase agreement between the Company and the various former holders of the Alta Mesa Project. The Lease now covers uranium, thorium, vanadium, molybdenum, other fissionable minerals, and associated minerals and materials under 4,597.67 acres. The term of the amended lease is fifteen (15) years commencing on June 16, 2016 or so long as the lessee is continuously engaged in any mining, development, production, processing, treating, restoration or reclamation operations on the leased premises. The amended lease can be extended by the Lessee for an additional 15 years upon payment of a stipulated cash payment. The lease includes provisions for royalty payments on the net proceeds (less allowable deductions) received by the Lessee. The royalty payment is 7.5% of Market Value of Product sold at a uranium price greater than $95.00 per pound, 6.25% of Market Value of Product sold at a uranium price greater than $65.00 and up to and including $95.00 per pound, and 3.125% of the Market Value of Product sold at a uranium price of $65.00 or less per pound. The Uranium Testing Permit and Lease Option Agreement, originally dated August 1, 2006, covers all of the land containing mineral potential as identified through exploration efforts and covers uranium, thorium, vanadium, molybdenum, and all other fissionable materials, compounds, solutions, mixtures, and source materials, has been superseded by the Amended and Restated Uranium Testing and Lease Option Agreement dated June 16, 2016, as part of the share purchase agreement between the Company and the various holders of the Alta Mesa Project. It now covers some 195,501.03 acres. The term of the amended lease and option agreement is for eight years commencing June 16, 2016. The amended lease and option agreement can be extended by the grantee for an additional seven years. Certain payments by the Grantee to the Grantor are required prior to year three of the initial eight year lease. The amended Lease Option Agreement provides for designating acreage to be leased for production by making certain payments to the Grantor (cash or stock). If acreage designation occurs within the first three years of the initial eight year lease, the payments will be deducted from the certain payments required by year three in the lease option agreement. The grantor then has sixty business days to execute and return the lease. Amended surface use agreements have been entered into with all of the surface owners on the various prospect areas as part of the Membership Interest purchase agreement between the Company and the various former holders of the Alta Mesa Project. These amended agreements, unchanged from those originally entered into on June 1, 2004, provide, among other things, for stipulated damages to be paid for certain activities related to the exploration and production of Uranium. Specifically, the agreements call for Consumer Price Index adjusted payments for the following disturbances: exploratory test holes, development test holes, monitor wells, new roads, and related surface disturbances. The lease also outlines an annual payment schedule for land taken out of agricultural use around the area of a deep disposal well, land otherwise taken out of agricultural use, and pipelines constructed outside of the production area. Surface rights are expressly stated in the lease and in general provide the lessee with the right to ingress and egress, and the right to use so much of the surface and subsurface of the leased premises as reasonably necessary for ISR mining. Open pit and/or strip mining is prohibited by the lease. 58 Ad valorem tax rates per $100 of taxable value applicable to tangible property for 2016 were as follows: Brooks County Brooks County Rd and Bridge Brooks County ISD Brooks County FM FC Brush Country Groundwater 0.743829 0.150000 1.572555 0.098837 0.026020 Permitting and Licensing The Alta Mesa Project area is fully permitted for ISR mining and recovery of uranium. The table below summarizes the current permits held by EFR Alta Mesa. Similar permits would be required for the Mesteña Grande project area depending upon the nature of operations and their integration with the Alta Mesa facility. Primary Permits and Licenses for the Alta Mesa Project Permit, License or Approval Name Radioactive Material License Class III UIC Mine Area Permit Aquifer Exemption Production Area Authorization Class I UIC Deep Disposal Well Permits * TCEQ= Texas Commission on Environmental Quality Agency TCEQ TCEQ TCEQ TCEQ TCEQ Status Obtained Obtained Obtained Obtained Obtained The ISR processing facility at Alta Mesa has an operating capacity of 1.5 million pounds of uranium per year. Primary regulatory authority resides with the State of Texas. Financial assurance instruments are held by the state for completed wells, ISR mining, and uranium processing to ensure reclamation and restoration of the affected lands and aquifers in accordance with state regulations and permit requirements. History Alta Mesa was first discovered in the mid 1970’s by Chevron Resources as a result of researching oil and gas logs for natural gamma geophysical signatures. Chevron controlled the Alta Mesa portion of the project through June of 1985 when they returned the mineral lease due to Chevron exiting the uranium business. Chevron reportedly drilled a total of 360 holes inclusive of exploration drilling, coring, and well completion during a four-year period from 1981 through 1984. In July of 1988 Total Minerals Incorporated (“Total”) executed a lease agreement for the Alta Mesa portion of the project. Total also engaged Uranium Resources Incorporated (“URI”) to complete a feasibility study for the project. The Total mineral lease was terminated as a result of the French Government requiring Total to sell all of their uranium assets to Cogema. Subsequently, the Project was evaluated by Cogema in 1994 and later by URI. URI held the mineral lease and obtained the Radioactive Material License during the period of 1996 through 1998. EFR Alta Mesa (previously named "Mesteña Uranium LLC") was formed in 1999 and continued permitting activities in April of 2000 and completed licensing in 2003. Plant construction at Alta Mesa began in 2004 with initial production in the 4th quarter of 2005. The Project produced approximately 4.6 million pounds of uranium oxide between 2005 and 2013 via ISR mining. The facility was in production from 2005 until primary production ceased in February 2013. The Project operated in a groundwater clean-up mode until February 2015; therefore, any uranium mined since 2013 remains as in- circuit inventory. The Alta Mesa Project is located within the Texas Gulf Coast along a belt of Tertiary and Quaternary sedimentary formations. The Project is located within the South Texas Uranium Province, which is known to contain more than 100 uranium deposits that were developed in the second half of the 20th century. Geology 59 Regionally, uranium deposits are hosted by four formations: • Miocene/Pliocene Goliad Formation, consisting of fluvial deposits, mostly unconsolidated sands. • Miocene Oakville Formation, consisting of fluvial deposits (sands, some clay). • Oligocene/Miocene Catahoula Formation, consisting of fluvial deposits, mostly sands, clay, and clastic volcanic rich sediments. • The Jackson Group consisting of fluvial deposits sands, silt, clay, and lignite. At the Alta Mesa Project, in order of importance, uranium is hosted by the Goliad, Oakville, and Catahoula formations. South Texas uranium deposits are sandstone roll-front uranium deposits. The key components in the formation of roll-front type mineralization include: • A permeable host formation: Sandstone units of the Goliad, Oakville, and Catahoula formations. • A source of soluble uranium: Volcanic ash-fall tuffs coincidental with Catahoula deposition containing elevated concentration of uranium is the probable source of uranium deposits for the South Texas Uranium Province. • Oxidizing ground waters to leach and transport the uranium: Ground waters regionally tend to be oxidizing and slightly alkaline. • Adequate reductant within the host formation: Conditions resulting from periodic H2S gas migrating along faults and subsequent iron sulfide (pyrite) precipitation created local reducing conditions. • Time sufficient to concentrate the uranium at the oxidation/reduction interface. Uranium precipitates from solution at the oxidation/reduction boundary (REDOX) as uraninite which is dominant (UO2, uranium oxide) or coffinite (USiO4, uranium silicate). The geohydrologic regime of the region has been stable over millions of years with ground water movement controlled primarily by high-permeability channels within the predominantly sandstone formations of the Tertiary. The structural map of the Gulf Coast area is dominated by an abundance of growth faults that trend with, or are slightly oblique to, stratigraphic strike, which is more or less parallel to the Gulf of Mexico. In addition, local structural features such as salt domes influence the distribution and deposition of uranium mineralization potentially through various mechanisms including effects on ground water flow and the introduction of additional reductant via the migration of H2S gas along the faulting related to the salt dome intrusion. This mechanism is thought to be of importance at Alta Mesa. Mineralization The Alta Mesa Project is located in the South Texas Uranium Province. Mineralization within the South Texas Uranium Province is interpreted to be dominantly roll-front type mineralization and primarily of epigenetic origin. Roll-fronts are formed along an interface between oxidizing ground water solutions, which encounter reducing conditions within the host sandstone unit. This boundary between oxidizing and reducing conditions is often referred to as the REDOX interface or front. Mineralization tends to be very continuous. Within the Alta Mesa portion of the Project, Quaternary formations are exposed at the surface. These are conformably underlain by the Goliad Formation, the primary uranium host. Alta Mesa ISR mine units have exploited uranium mineralization in the Goliad C sands within wellfields PAA-1, PAA-2, PAA-3, PAA-4, and PAA-6. The B sand was targeted in wellfield PAA-5. Mineral resources have been estimated for the A, B, C, and D sands. Exploration targets in the South Alta Mesa area lie within successively deeper D, E, F, G, and H sands of the Goliad. Within the Mesteña Grande portion of the project, mineralization is also present in the Goliad Formation but is dominantly found in the Oakville Formation. In the western portion of Mesteña Grande mineralization is found in the Catahoula Formation. Mineral resources have been estimated for all areas within the Mesteña Grande portion of the project. Present Condition of the Property and Work Completed to Date The Alta Mesa Project produced approximately 4.6 million pounds of uranium oxide between 2005 and 2013 via In Situ Recovery mining. The facility was in production from 2005 until primary production ceased in February 2013. The Project operated in a groundwater clean-up mode until February 2015; therefore, any uranium mined since 2013 remains as in-circuit inventory. The first wellfield (PAA-1) has undergone restoration and is currently being monitored for restoration stability. All other wellfields are being maintained by a small bleed (less than 100 gpm) for permit compliance. The bleed solutions are disposed of in the deep disposal wells. Drill data is available for a total of 10,744 drill holes of which approximately 3,000 are within existing wellfields. The primary assay data for the Project is downhole geophysical log data. EFR Alta Mesa relied entirely on prompt-fission-neutron ("PFN") logging for 60 uranium grade assay and used natural gamma logging to screen intervals for PFN logging. Of the 10,744 drill holes in the Alta Mesa database, PFN logging was not available for only 7.2% of the drill holes. For the Mesteña Grande portion of the Project, all 460 drill holes were completed by EFR Alta Mesa and all gamma intercepts greater than 0.02 % eU3O8 were logged by PFN. For determination of uranium grade, EFR Alta Mesa LLC relied on PFN log data for 92.8% of the data, which is a direct measurement of uranium content and not an equivalent radiometric assay. As a result, assessment of disequilibrium factor ("DEF") is not applicable. As of December 31, 2017, the total cost attributable to the Alta Mesa Project on the Company's financial statements was $13.63 million. The Company’s Planned Work During 2018, the Company expects to maintain the Alta Mesa Project on standby. However, Alta Mesa is capable of ramping up to commercial production levels within approximately six months of a positive production decision by the Company, with only minimal capital requirements. Mineral Resource Estimates Mineral resources have been estimated for both the Alta Mesa and Mesteña Grande areas by Douglas Beahm of BRS Inc. in accordance with CIM standards and definitions, and are summarized in the respective tables below. Mineral Resources for the Alta Mesa Project are estimated by classifications, meeting CIM standards and definitions as measured, indicated, and inferred mineral resources, at a 1.30 GT cutoff. There are no Mineral Reserves on the property at this time. Mr. Beahm of BRS Inc. noted that he is not aware of any known environmental, permitting, legal, title, taxation, socioeconomic, marketing, political, or other relevant factors that could materially affect the current resource estimate. Alta Mesa and Mesteña Grande Resource Summary Alta Mesa and Mesteña Grande Mineral Resources – Uranium(1)(2)(3)(4) Classification Total Measured Resources (M)(5) Alta Mesa Indicated Resources (I) Mesteña Grande Indicated Resources (I) Total (M & I) Alta Mesa Inferred Resources Mesteña Grande Inferred Resources Total Inferred Resources Notes: Tons (000) Grade % eU3O8 Pounds eU3O8 (000) 123 0.151% 1,393 0.106% 119 0.120% 1,635 0.111% 1,230 0.128% 371 2,959 287 3,617 3,192 5733 0.119% 13,601 6,963 0.121% 16,793 (1) The Mineral Resource estimate in this table complies with the requirements of NI 43-101 and the classifications comply with CIM definition standards and do not represent reserves under SEC Industry Guide 7. Mineral resources that are not reserves do not have demonstrated economic viability. See “Cautionary Note to U.S. Investors Concerning Disclosure of Mineral Resources,” above. (2) Mineral Resources are estimated at a uranium grade x thickness (G.T.) cut-off grade of 0.30 G.T. (minimum 0.02% eU3O8). (3) Mineral Resources are estimated using a long-term uranium price of US$65 per pound. (4) Numbers may not add due to rounding. (5) The Total Measured Mineral Resource is that portion of the in-place mineral resource that is estimated to be recoverable within existing wellfields. Wellfield recovery factors have not been applied to indicated and inferred mineral resources. 61 The White Mesa Mill General The White Mesa Mill is a fully licensed uranium and vanadium processing facility located in southeastern Utah, approximately six miles south of the city of Blanding, Utah. It is within trucking distance of our conventional properties in Utah, Colorado, Arizona and New Mexico, including the Canyon Project, the Roca Honda Project, the Henry Mountains Complex, the La Sal Project and the Daneros Project. The Mill is the only fully operational and licensed conventional uranium mill in the U.S. It is capable of functioning independently of off-site support except for commercial power from Rocky Mountain Power and as-needed supplemental water supply from the City of Blanding, Utah, and the San Juan Water Conservancy District. The White Mesa Mill is a uranium processing and recovery facility. It is not an underground or open pit project. The Mill is licensed to process an average of 2,000 tons of ore per day and to extract over 8.0 million pounds of U3O8 per year. In addition to the conventional circuit, the Mill has a separate vanadium by-product recovery circuit. In addition to the Mill processing equipment, which includes the grinding and leaching circuits, CCD (liquid–solid separation), solvent extraction, and precipitation and drying circuits, the Mill has several days of reagent storage for sulfuric acid, ammonia, salt, soda ash, caustic soda, ammonium sulfate, flocculants, kerosene, amines, and liquefied natural gas. The on-site infrastructure also includes a stockpile area capable of storing up to 450,000 tons of mineralized material, and existing tailings capacity of approximately 3.5 million tons of solids. In addition, the Mill has approximately 90 acres of evaporation capacity. Synthetic lined cells are used to contain tailings and solutions for evaporation. We operate two tailings cells and one or more evaporation ponds during normal operations. As each tailings cell is filled, the water is drawn off and pumped to an evaporation pond and the 62 tailings solids are allowed to dry. As each tailings cell reaches final capacity, reclamation begins with the placement of interim cover over the tailings. Additional cells are excavated, and the overburden is used to reclaim previous cells. In this way, there is an ongoing reclamation process. In full operation, the Mill employs approximately 150 people. If no Vanadium ores are being processed, the Mill employs approximately 110 people. Alternate Feed Materials The Mill License (defined below) also gives the Company the right to process other uranium-bearing materials known as “alternate feed materials” pursuant to an Alternate Feed Guidance published by the NRC. Alternate feed materials are uranium-bearing materials, usually classified as waste products by the generators of the materials, which can be recycled by the Mill for the recovery of U3O8. The Mill License does not permit the processing of uranium-bearing materials that have undergone enrichment. Requiring a routine amendment to the Mill License for each different alternate feed material, the Company can process these uranium-bearing materials and recover uranium, in some cases, at a fraction of the cost of processing conventionally mined material. In other cases, the generators of the alternate feed materials are willing to pay a recycling fee to the Company to process these materials to recover uranium and then dispose of the remaining by-product in the Mill’s licensed tailings cells, rather than directly disposing of the materials at a disposal site. By working with the Company and taking the recycling approach, the suppliers of alternate feed materials can significantly reduce their remediation costs, as there are only a limited number of disposal sites for such materials in the United States. Alternate feed materials are particularly attractive to Energy Fuels because they carry no associated mining costs. Throughout its history, the Mill has received 17 license amendments, authorizing it to process 20 different alternate feed materials. Of these amendments, eleven have involved the processing of feeds provided by nuclear fuel cycle facilities and private industry, and one has involved the processing of material from the United States Department of Energy (“DOE”). These twelve feed materials have been relatively high in uranium content and relatively low in volume. The remaining five amendments have allowed the Mill to process uranium-bearing soils from former defense sites, known as FUSRAP sites, which were being remediated by the U.S. Army Corps of Engineers. These materials are typically relatively low in uranium content but relatively high in volume. The Mill has a separate circuit for processing certain types of alternate feed materials, which was built in 2009. This circuit enables the Mill to process both conventionally mined material and alternate feed materials simultaneously. Accessibility, Local Resources, Physiography and Infrastructure The Mill is located in central San Juan County, Utah, approximately six miles (9.5 km) south of the city of Blanding. It can be reached by taking a private road for approximately 0.5 miles west of U.S. Highway 191. The climate of southeastern Utah is classified as dry to arid continental. Although varying somewhat with elevation and terrain, the climate in the vicinity of the Mill can be considered as semi-arid with normal annual precipitation of about 13.4 inches. The weather in the Blanding area is typified by warm summers and cold winters. The mean annual temperature in Blanding is about 50° (F). Winds are usually light to moderate in the area during all seasons, although occasional stronger winds may occur in the late winter and spring. The Mill site is located on a gently sloping mesa that, from the air, appears similar to a peninsula, as it is surrounded by steep canyons and washes and is connected to the Abajo Mountains to the north by a narrow neck of land. On the mesa, the topography is relatively flat, sloping at less than one (1) percent to the south and nearly horizontal from east to west. The natural vegetation presently occurring within a 25-mile (40-km) radius of the Mill site is very similar to that of the region, characterized by pinyon-juniper woodland integrating with big sagebrush (Artemisia tridentata) communities. Off-site infrastructure includes paved highway access from U.S. Highway 191, and rights-of-way for commercial power and a water supply pipeline from Recapture Reservoir, which brings up to 1,000 acre-feet of water per year to the Mill site. The Mill also has four deep (2,000+ foot) water supply wells, which are available to supply process water during normal operations. The White Mesa Mill is located on 4,816 acres of private land owned in fee by Energy Fuels. This land is located in Township 37S and 38S Range 22E Salt Lake Principal Meridian. Energy Fuels also holds 253 acres of mill site claims and a 320 acre Utah state lease. No facilities are planned on the mill site claims or leased land, which are used as a buffer to the operations. Ownership 63 All operations authorized by the Mill’s License are conducted within the confines of the existing site boundary. The milling facility currently occupies approximately 50 acres and the current tailings disposal cells encompass another 250 acres. Permitting and Licensing The White Mesa Mill holds a Radioactive Materials License through the State of Utah (the “Mill License”). Uranium milling in the U.S. is primarily regulated by the NRC pursuant to the Atomic Energy Act of 1954, as amended. The NRC’s primary function is to ensure the protection of employees, the public and the environment from radioactive materials, and it also regulates most aspects of the uranium recovery process. The NRC regulations pertaining to uranium recovery facilities are codified in Title 10 of the Code of Federal Regulations. These regulations also apply to our ISR facilities in Wyoming and Texas. On August 16, 2004, the State of Utah became an Agreement State for the regulation of uranium mills. This means that the primary regulator for the White Mesa Mill is UDEQ rather than the NRC. At that time, the Source Material License, which was previously issued and regulated by the NRC, was transferred to the State and became a Radioactive Materials License. The State of Utah incorporates, through its own regulations or by reference, all aspects of Title 10 pertaining to uranium recovery facilities. The Mill License was due for renewal on March 31, 2007. Energy Fuels’ predecessor timely submitted its application for renewal of the license on February 28, 2007. The renewed license was issued by UDEQ on January 19, 2018 for a period of ten years, after which another application for renewal will need to be submitted. During the review period for each application for renewal, the Mill can continue to operate under its then existing license until such time as the renewed license is issued. The Mill’s license was initially issued in 1980 and was also renewed in 1987 and 1997. When the State of Utah became an Agreement State, it required that a Groundwater Discharge Permit (“GWDP”) be put in place for the White Mesa Mill. The GWDP is required for all similar facilities in the State of Utah, and implements the State groundwater regulations to the Mill site. The State of Utah requires that every operating uranium mill have a GWDP, regardless of whether or not the facility discharges to groundwater. The GWDP for the Mill was finalized and implemented in March 2005. The GWDP required that the Mill add over 40 additional monitoring parameters and 15 additional monitoring wells at the site. The GWDP came up for renewal in 2010, at which time an application for renewal was timely submitted. The renewed GWDP was issued by UDEQ on January 19, 2018 for a period of five years, after which another application for renewal will need to be submitted. During the review period for each application for renewal, the Mill can continue to operate under its then existing GWDP until such time as the renewed GWDP is issued. The White Mesa Mill also maintains a permit for air emissions with the UDEQ, Division of Air Quality. The White Mesa Mill is subject to decommissioning liabilities. Energy Fuels, as part of the Mill License, is required to annually review its estimate for the decommissioning of the White Mesa Mill site and submit it to UDEQ for approval. The estimate of closure costs for the Mill is $20.8 million as of December 31, 2017, and financial assurances are in place for the total amount. However, there can be no assurance that the ultimate cost of such reclamation obligations will not exceed the estimated liability contained in the Company’s financial statements. History The Mill was originally constructed and owned by Energy Fuels Nuclear, Inc. (“EFN”) and its affiliates (no relation to the Company). It was licensed by the NRC and commenced operations in June 1980. In 1984, EFN transferred a 70% interest in the Mill to UMETCO Minerals Corp., a subsidiary of Union Carbide Corporation (“UMETCO”). UMETCO became the operator of the Mill in 1984 and continued to be the operator until 1994, at which time it transferred its interest in the Mill back to EFN and its affiliates. The Mill was acquired by Denison Mines Corp. (“Denison”), then named International Uranium Corporation (“IUC”) and its affiliates in 1997, and was operated by Denison until it was acquired by the Company in June 2012. From the original commissioning in 1980 through December 31, 2017, the Mill has recovered a total of approximately 38 million pounds of U3O8 and 46 million pounds of vanadium. In late 2006, Denison began a program to refurbish the Mill. The refurbishment program included the purchase of mobile equipment, restoration of the vanadium roasting, fusion and packaging circuits, replacement of major pumps and component drives, modernization of the Mill’s instrumentation and process control systems, and completion of relining tailings Cell 4A. The total cost of the refurbishment program was approximately $31.0 million and was completed in 2008. The White Mesa Mill has historically operated on a campaign basis. In 2008, the Mill began processing uranium/vanadium conventional mined material, extracting uranium concentrate in the form of U3O8, and vanadium in the form of V2O5. Mineral processing continued through the end of March 2009, at which time maintenance activities were performed at the Mill. Mineral processing recommenced near the end of April 2009, but was discontinued due to a decline in uranium prices at the time. The Mill began mineral processing again in March 2010 and continued through June 2011. Conventional processing recommenced in November 2011 and continued until early March 2012, at which time it ceased for routine maintenance. Conventional mineral processing recommenced at the Mill in August 2012 and continued until early June 2013. Mineral processing began again in May 2014 and continued through August 2014. 64 The alternate feed circuit processed materials from January through December 2014, and continued processing alternate feed materials through December 2015. In 2016, the Company continued processing several alternate feed materials and processed 45,057 tons of mineralized material from its Pinenut mine. In 2017 the Mill continued processing alternate feed materials as well as the recovery of uranium from pond solutions at the site. Energy Fuels acquired the Mill from Denison Mines Corp. on June 29, 2012. All mineral processing after that date has been for the account of Energy Fuels. Mineral processing at the Mill over the past five years is shown below. Note, only mineral processing since June 30, 2012 has been for the account of Energy Fuels.(1) Project or Source 2017 2016 2015 2014 2013 Alternate Feed Materials(2) Tons (000) NA(2) NA(2) NA(2) NA(2) NA(2) Ave. % U3O8 18.86% 27.98 9.21 16.94% 5.03% Recovered Pounds U3O8 (000) 1,004(3)(4) 172(3)(4) 229(3) 391(3) 351(3) Tailing Solution Recycle & In-Circuit Material(5) Conventional Feed Materials Recovered Pounds U3O8 (000) 308 78 67 --- --- Tons (000) Contained Grade % U3O8 Recovered Pounds U3O8 (000) Total Pounds of U3O8 Recovered (000) Total Pounds of V2O5 Recovered (000) Notes: --- --- --- 1,312 45 0.50% 431 681 --- --- --- 296 49 126 0.56% 0.26% 552 943 655 1,006 1,303 (1) Mineralized material is shown as being processed and pounds recovered during the year in which the materials were processed at the White Mesa Mill, which is not necessarily the year in which the materials were extracted from the project facilities. (2) All alternate feed materials were processed at the White Mesa Mill. A number of different alternate feed materials were processed during the period 2013 - 2017. The table shows the average uranium grades and the total pounds recovered from all alternate feed materials processed at the Mill during each of the years in that period. Because of the variability in uranium grades, pounds recovered is considered to be the relevant metric and tons fed is not considered to be relevant. (3) The 1,004,000 pounds recovered in 2017 include 952,000 pounds recovered for the accounts of third parties; the 172,000 pounds recovered in 2016 includes nil pounds recovered for the accounts of third parties; the 229,000 pounds recovered in 2015 includes 72,000 pounds recovered for the accounts of third parties; the 391,000 pounds recovered in 2014 includes 85,000 pounds recovered for the accounts of third parties; and the 351,000 pounds recovered in 2013 includes nil pounds recovered for the accounts of third parties. (4) Material recovered originated from several different sources that were fed to process at various times in 2015 and 2016. Therefore, the recovered amount is independent of the reported feed amount for any given period. (5) Pounds contained in tailings solutions containing previously unrecovered uranium, together with in-circuit mineralized material from previous conventional mine material processing, were recovered by processing alternate feed materials at the White Mesa Mill, though tons and grade are not available because it cannot be tied to any specific source. Planned Operations and Maintenance Present Condition of the Property The White Mesa Mill processed conventional material from June to mid-August 2014. The alternate feed circuit was operating throughout 2014 and 2015, and stopped processing materials in July of 2016. The White Mesa Mill processed conventional mineralized material in the second and third quarter of 2016 and processed alternate feed materials during the remainder of the year. In 2017, the Mill 65 processed only alternate feed materials and recovered uranium from pond solutions at the site. The Mill operations registered zero lost time accidents in 2017. Environmental Matters Prior to Energy Fuels’acquisition of the Mill from Denison, chloroform in the shallow aquifer at the White Mesa Mill site was discovered. The chloroform appears to have resulted from the operation of a temporary laboratory facility that was located at the site prior to and during the construction of the Mill, and from septic drain fields that were used for laboratory and sanitary wastes prior to construction of the Mill’s tailings cells. In April 2003, Denison commenced an interim remedial program of pumping the chloroform affected water from the groundwater to the Mill’s tailings system. This action enabled Energy Fuels to begin cleanup of the affected areas and to take a further step towards resolution of this outstanding issue. Pumping from the wells continued in 2015. On September 14, 2015, the State of Utah approved a long-term Corrective Action Plan (“CAP”) for cleanup of the chloroform, which involves continued pumping of the affected water to the Mill’s tailings system. While the investigations to date indicate that this chloroform appears to be contained in a manageable area, the scope and costs of final remediation have not yet been determined and could be significant. Prior to Energy Fuels’ acquisition of the Mill from Denison, elevated concentrations of nitrate and chloride were observed in some of the monitoring wells at the White Mesa Mill site in 2008, a number of which are upgradient of the Mill’s tailings cells. Pursuant to a Stipulated Consent Agreement with UDEQ, Denison retained INTERA, Inc., an independent professional engineering firm, to investigate these elevated concentrations and to prepare a Contamination Investigation Report for submittal to UDEQ. The investigation was completed in 2009, and the Contamination Investigation Report was submitted to UDEQ in January 2010. INTERA concluded in the Report that: (1) the nitrate and chloride are co-extensive and appear to originally come from the same source; and (2) the source is upgradient of the Mill property and is not the result of Mill activities. UDEQ reviewed the Report, and concluded that further investigations were required before it could determine the source of the contamination and the responsibility for cleanup. Such investigations were performed in 2010 and 2011, but were considered to be inconclusive by UDEQ. As a result, after the investigations, it was determined that there are site conditions that make it difficult to ascertain the source(s) of contamination at the site, and that it was not possible at that time to determine the source(s), causes(s), attribution, magnitude(s) of contribution, and proportion(s) of the local nitrate and chloride in groundwater. For those reasons, UDEQ decided that it could not eliminate Mill activities as a potential cause, either in full or in part, of the contamination. The Company and UDEQ have therefore agreed that resources are better spent in developing a CAP, rather than continuing with further investigations as to the source(s) and attribution of the groundwater contamination. Pursuant to a revised Stipulated Consent Agreement, Denison submitted a draft CAP for remediation of the contamination to UDEQ in November 2011. The CAP proposed a program of pumping the nitrate contaminated groundwater to the Mill’s tailings cells, similar to the chloroform remedial program. UDEQ approved the CAP on December 12, 2012. In accordance with the CAP, in 2013 the Company commenced pumping nitrate/chloride contaminated water from four monitoring wells for use in Mill processing or discharge into the Mill’s process or tailings cells. Although the contamination appears to be contained in a manageable area, the scope and costs of final remediation have not yet been determined and could be significant. During 2011, 2012, and 2013, the White Mesa Mill reported consecutive exceedances of groundwater compliance limits (“GWCLs”) under the Mill’s GWDP for several constituents in several wells, and there are decreasing trends in pH in a number of wells across the site that have caused the pH in a number of compliance monitoring wells to have dropped below their GWCLs. These exceedances and pH trends include wells that are up-gradient of the Mill facilities, far down-gradient of the Mill site and at the site itself. These consecutive exceedances of GWCLs have resulted in violations of the GWDP. Source Assessment Reports were submitted in 2012 and 2013 addressing each exceedance and the decreasing trends in pH at the site. UDEQ has accepted the Source Assessment Reports, and has concluded that such exceedances and decreasing trends in pH are due to natural background influences at the site. The renewed GWDP, issued on January 19, 2018, has revised GWCLs which are intended to account for these background influences and put those constituents, including pH at the site, back into compliance. Total Cost of Project The White Mesa Mill was acquired by the Company in June 2012, through the acquisition of the US Mining Division from Denison. The cost of the White Mesa Mill has been fully impaired, and as of December 31, 2017, the total cost attributable to the White Mesa Mill and its associated equipment on the financial statements of the Company was nil. The Company’s Planned Work The Company continues to process alternate feed material at the White Mesa Mill. During 2018 the Mill is expected to continue alternate feed processing and the recovery of uranium from uranium dissolved in the Mill's ponds, as well as to pursue additional alternate feed materials and other sources of feed for the Mill, as well as evaluate the possibility of recovering vanadium from existing pond solutions at the Mill. 66 The Canyon Mine Except as noted, the following technical and scientific description of the Canyon Project is based on a technical report titled “Technical Report on the Canyon Mine, Coconino County, Arizona, U.S.A.”, dated October 6, 2017 prepared by Mark B. Mathisen, C.P.G., Valerie Wilson, M.Sc., P.Geo, and Jeffrey L. Woods, QP MMSA, SME of RPAin accordance with NI 43-101 (the “Canyon Technical Report”). Each of the authors of the Canyon Technical Report is a “qualified person” and is “independent” of the Company within the meaning of NI 43-101. The Canyon Technical Report is available on SEDAR at www.sedar.com. The Canyon Project does not have known reserves, and is therefore considered under SEC Industry Guide 7 definitions to be exploratory in nature, despite currently ongoing development activities. Property Description and Location The Canyon Project is a fully constructed and partially developed underground uranium project with: a head frame, a hoist, a compressor and a completed shaft. The site is located south of Grand Canyon National Park, in Sections 19 and 20, T29N, R03E, GSRM, Coconino County, Arizona, 153 miles north of Phoenix, 86 miles northwest of Flagstaff and seven miles south of Tusayan, Arizona in the Kaibab National Forest. The Canyon Project was acquired by Energy Fuels in its June 2012 acquisition of Denison’s US Mining Division. The Canyon Project is located in the Arizona Strip mining district. The Arizona Strip is an area largely bounded on the north by the Arizona/Utah state line; on the east by the Colorado River and Marble Canyon; on the west by the Grand Wash Cliffs; and on the south by a midpoint between the city of Flagstaff and the Grand Canyon. The area encompasses approximately 13,000 square miles. Uranium- bearing material from the Arizona Strip mines is hauled by truck to the White Mesa Mill where it is processed. The Company’s Arizona 1, Pinenut (now in reclamation) and EZ Projects are located north of the Grand Canyon. The Canyon Project and Wate Project are located south of the Grand Canyon. The Canyon Project is 325 road miles from the Mill. 67 Accessibility, Climate, Local Resources, Infrastructure and Physiography Access to the Canyon Mine site is via State Highway 64 and Federal Highway 180 to within five miles of the mine site, then over unsurfaced public Forest Service roads. The Atchison, Topeka and Santa Fe railway line passes east-west 50 mi. south of the site at Williams, and a spur of the railway, which passes 10 mi. west of the Canyon Mine site, services the Grand Canyon National Park. Airports at Flagstaff, Phoenix, and Tusayan provide air access to the area. Climate in northern Arizona is semi-arid, with cold winters and hot summers. January temperatures range from about 7° F to 57° F and July temperatures range from 52° F to 97° F. Annual precipitation, mostly in the form of rain but some snow, is about 12 inches. Vegetation on the plateaus is primarily open piñon juniper woodland and shrubs. Mining operations can be conducted on a year-round basis. The community of Tusayan, seven miles northwest of the Canyon Mine, provides much of the housing and other facilities for people who work within Grand Canyon National Park. Seasonal population is from 500 to 1,000. A clinic run by a Phoenix hospital is operated at Grand Canyon Village inside the national park, as well as a K-12 grade school with a capacity of 250 students. Williams, a rural community, 44 miles south of the site at Interstate 40, has a population of approximately 2,500. Williams relies heavily on tourism to maintain its economy, but many people are also involved in agriculture and forestry. The town offers an elementary, middle and high school, an emergency medical center, shopping and a variety of community services. Although housing is available, lack of adequate water supplies has limited housing construction. Flagstaff, 56 miles southeast of the Canyon Mine, is a full-service city with a population of 70,000 and is the regional trade center for northern Arizona. 68 Arizona, and particularly Coconino County, is among the fastest growing areas in the United States, due to the climate, landscape diversity, and economic and recreational opportunities. Resources and services are often stretched to meet the needs of the growing population. Personnel for future mining operations are expected to be sourced from the nearby towns of Williams and Flagstaff, as well as other underground mining districts in the western United States. In addition to the mine shaft, existing mine infrastructure includes surface maintenance shops, employee offices and change rooms, a water well, an evaporation pond, explosives magazines, water tank, fuel tank, and rock stockpile pads. Electrical power is available through an existing power line that terminates at the site. Northern Arizona is part of the Colorado Plateau, a region of the western United States characterized by semi-arid, high-altitude, gently sloping plateaus dissected by steep walled canyons, volcanic mountain peaks, and extensive erosional escarpments. The Canyon Mine is located on the Coconino Plateau within the Colorado Plateau, at an elevation of approximately 6,500 ft. Ownership The Canyon Project is held by Energy Fuels on nine unpatented claims (Canyon 64-66, 74-76, and 84-86) located on land managed by the USFS. A uranium royalty has been retained by the successors to Gulf Oil Company on the Property, however, the current validity of the royalty is under investigation by Energy Fuels. If valid, the royalty rate is a 3.5% weighted average price tied to the Atomic Energy Commission Circular 5. Holding costs for the Canyon Project are minimal and consist entirely of annual fees for unpatented mining claims ($155 per claim per year) and county filing fees (approximately $10 per claim per year). Unpatented mining claims expire annually, but are subject to indefinite annual renewal by filing appropriate documents and paying the fees described above. In addition, holders of unpatented mining claims on USFS lands are generally granted surface access by the USFS to conduct mineral exploration and mining activities. Permitting and Licensing The Canyon Project is located on public lands managed by the USFS and has an approved PO with the USFS. In September 2009, the groundwater General Aquifer Protection Permit was received for the water storage ponds. This permit was renewed in 2014. An Air Quality Permit was issued by the Arizona Department of Environmental Quality in March 2011, renewed in 2016 and amended in 2017. The Company received EPA’s approval under the Clean Air Act National Emissions Standard for Hazardous Air Pollutants for the Canyon Project in September of 2015. Development of uranium-bearing breccia pipes of the Arizona Strip requires minimal surface disturbance, typically less than 20 acres. The overall environmental impact is small. Nevertheless, the areas in the vicinity of the Grand Canyon can be environmentally sensitive in many ways, and the permitting, development, and operation of a uranium extraction facility in this area has been a contentious issue. In 2009, as described below, over one million acres of federal land were withdrawn from mineral location, subject to valid existing rights. Reclamation at the Canyon Project is bonded at its total expected cost. Geological Setting Parts of two distinct physiographic provinces are found within Arizona: the Basin and Range province in the southern and western edge of the state, and the Colorado Plateau province in most of northern and central Arizona. The Arizona Strip lies within the Colorado Plateau province. Surface exposures within the Arizona Strip reveal sedimentary and volcanic rocks ranging in age from upper Paleozoic to Quaternary; the area is largely underlain by Mississippian through Triassic sedimentary rocks. However, exposed within the Grand Canyon are older rocks reaching Precambrian in age. Paleozoic sedimentary rocks of northern Arizona are host to thousands of breccia pipes. These deposits are known to extend from the Mississippian Redwall Limestone to the Triassic Chinle Formation, which makes about 4,000 feet of section. However, because of erosion and other factors, no single deposit has been observed cutting through the entire section. No deposit is known to occur above the Chinle Formation or below the Redwall Limestone. Breccia pipes within the Arizona Strip are vertical or near vertical, circular to elliptical bodies of broken rock. Broken rock is comprised of slabs and rotated angular blocks and fragments of surrounding and stratigraphically higher formations. Surrounding the blocks and 69 slabs making up the breccia is a matrix of fine material comprised of surrounding and overlying rock from various formations. The matrix has been cemented by silicification and calcification for the most part. Breccia pipes are typically comprised of three interrelated features: a basinal or structurally shallow depression at surface (designated by some as a collapse cone); a breccia pipe that underlies the structural depression; and annular fracture rings, which occur outside of, but at the margin of the pipes. Annular fracture rings are commonly, but not always, mineralized. The structural depression may be up to 0.5 miles or more in diameter, whereas the breccia pipe diameters range up to about 600 feet; the normal range is 200 feet to 300 feet. Mineralized breccia pipes found to date appear to occur in clusters or trends. Spacing between breccia pipes ranges from hundreds of feet within a cluster to several miles within a trend. Pipe location may have been controlled by deep seated faults, but karstification of the Redwall Limestone in Mississippian and Permian times is considered to have initiated formation of the numerous and widespread breccia pipes in the region. At the Canyon deposit, the surface expression of the pipe is a broad shallow depression in the Permian Kaibab Formation. The pipe is essentially vertical with an average diameter of less than 200 feet, but it is considerably narrower through the Coconino and Hermit horizons (80 feet). The cross sectional area is probably between 20,000 and 25,000 square feet. The pipe extends for at least 2,300 feet from the Toroweap limestone to the upper Redwall horizons. The ultimate depth of the deposit is unknown. Mineralization extends over about 1,500 vertical feet, with higher-grade mineralization found mainly in the Coconino, Hermit, and Esplanade horizons and at the margins of the pipe in fracture zones. Sulfide zones are found scattered throughout the pipe but are especially concentrated (sulfide cap) near the Toroweap Coconino contact, where the cap averages 20 feet thick and consists of pyrite and bravoite, an iron-nickel sulfide. The mineralized assemblage consists of uranium-pyrite-hematite with massive copper sulfide mineralization common in and near the higher-grade zone. The strongest mineralization appears to occur in the lower Hermit-upper Esplanade horizons in an annular fracture zone. History Uranium exploration and mining of breccia pipe uranium deposits started in 1951 when a geologist employed by the U.S. Geological Survey noted uranium ore on the dump of an old copper prospect on the South Rim of the Grand Canyon of Northern Arizona. The prospect was inside the Grand Canyon National Park, but on fee land that predated the park. A mining firm acquired the prospect and mined this significant high-grade uranium deposit, called the Orphan Mine. By the time mining ended in the early 1960s, 4.26 million pounds of U3O8 and some minor amounts of copper and silver had been produced. After the discovery of the first deposit in the 1950s, an extensive search for other deposits was made by the government and industry, but only a few low-grade prospects were found. Exploration started again in the early 1970s. In the mid-1970s, Western Nuclear Inc. (“Western Nuclear”) acquired the Hack Canyon prospect located about 25 miles north of the Grand Canyon and found high grade uranium mineralization offsetting an old shallow copper/uranium site. In the next few years, a second deposit was found approximately one mile away. EFN acquired the Hack Canyon property from Western Nuclear in December 1980. Construction started promptly, and the Hack Canyon mine was in production by the end of 1981. The Canyon deposit is located on mining claims that EFN acquired from Gulf Mineral Resources Company (“Gulf”) in 1982. Gulf drilled eight exploration holes at the site from 1978 through May 1982, but found only low-grade uranium in this pipe. Additional drilling completed by EFN in 1983 identified a major deposit. EFN drilled a further 30 holes from May 1983 through April 1985 to delineate the uranium mineralization and to determine placement of the shaft and water supply well. Additional drilling of six holes was completed in 1994. Construction at the site was discontinued as a result of low uranium prices at that time. EFN identified and investigated more than 4,000 circular features in northern Arizona. About 110 of the most prospective features were explored by deep drilling, and approximately 50% of those drilled were shown to contain some uranium mineralization. Ultimately, nine deposits were deemed worthy of development. Total mine production from the EFN breccia pipes from 1980 through 1991 was approximately 19.1million pounds U3O8 at an average grade of just over 0.60% U3O8. Most of the EFN assets were acquired by Denison (then named IUC) in 1997 and by the Company in June 2012 upon acquisition of the US Mining Division. Since that time, Denison and later Energy Fuels has maintained ownership of the Canyon Project. Denison did not carry out any surface exploration on the Canyon Project since its acquisition of the project in 1997, nor has the Company to date. Exploration for breccia pipes in northern Arizona typically begins with a search for surface expressions of circular features. This search was aided by geologic mapping, Landsat aerial photography, thermal infrared imagery, geochemical testing, and certain geophysical methods such as resistivity, Very Low Frequency ("VLF"), and time domain electromagnetics. Other techniques tested 70 included: geobotany, microbiology, and biogeochemistry. All of these methods were utilized to identify surface expressions of breccia pipes. The key element of the process was to zero in on the throat of the pipe as a locus for drilling from the surface since the throat is usually associated directly with the center of the collapse. Mineralization Mineralization extends vertically both inside and outside the pipe over about 1,500 vertical feet, but high-grade mineralization has been found mainly in the collapsed portions of the Coconino, Hermit, and Esplanade horizons and at the margins of the pipe in fracture zones. Sulfide zones are found scattered throughout the pipe but are especially concentrated (within a sulfide cap) near the Toroweap- Coconino contact, where the cap averages 20 feet thick and consists of pyrite and bravoite, and iron-nickel sulfide. The mineralization assemblage consists of uranium-pyrite-hematite with massive copper sulfide mineralization common in and near high-grade zones. The strongest mineralization appears to occur in the lower Hermit-upper Esplanade horizons in an annular fracture zone. The two metals of interest within the Canyon breccia pipe are uranium and copper. Since the rocks making up the breccia within the pipe are all sedimentary rocks, mineralization typically occurs within the matrix material (primarily sand) surrounding the larger clasts. Uranium mineralization at Canyon is concentrated in six stratigraphic levels or zones (Cap, Upper, Main, Main-Lower, Juniper I, and Juniper II) within a collapse structure ranging from 80 ft. to 230 ft. wide with a vertical extension from a depth of 650 ft. to over 2,100 ft., resulting in approximately 1,450 feet of mineralization. Intercepts range widely up to several tens of feet with grades in excess of 1.0% U3O8. Consistent with other breccia pipe deposits, uranium at Canyon Mine occurs largely as blebs, streaks, small veins, and fine disseminations of uraninite/pitchblende (UO2). Mineralization is mainly confined to matrix material, but may extend into clasts and larger breccia fragments, particularly where these fragments are composed of Coconino sandstone. Uranium mineralization occurs primarily as uraninite and various uranium phase minerals with lesser amounts of brannerite and uranospinite. Copper mineralization occurs in concentrations within the Main and Main-Lower zones that have a reasonable prospect for eventual economic extraction. It is also present in the Juniper zones, but at much lower concentrations than the Main zone. Mineralization can be disseminated throughout the matrix material (commonly replacing calcite cement) with higher-grade mineralization typically occurring as vug fills, blebs, or streaks within the matrix and sometimes zoning the breccia clasts. The highest grade copper mineralization either completely replaces the matrix cement or replaces the matrix material all together. Copper mineralization occurs primarily as tennantite, chalcocite and bornite with lesser amounts of covellite. Pyrite and sphalerite are also found throughout the pipe. Silver is commonly associated with the copper mineralization in the main zone. Assay values of silver in excess of one ounce per ton are common where copper grades are high. Arsenic is present where tennantite mineralization occurs. Additionally, lower quantities of Zn, Pb, Mo, Co, Ni, and V are present and scattered throughout the pipe. Mineral Resource Estimate Mineral Resource estimates were prepared for the Canyon deposit using both historical surface drill hole gamma and assay data and gamma and assay data collected during underground drilling in 2016 and 2017. A model of the breccia pipe host was constructed based on drill logs and constrains the Mineral Resource. Mineralization wireframes for U3O8 were based on assays and gamma data at a nominal cut-off grade of 0.15%. Low and high-grade copper wireframes were based on nominal cutoff grades of 1% and 8% respectively. Values for U3O8 and copper were interpolated into blocks using inverse distance squared or ordinary kriging. Resources are presented a 0.36% U3O8 Eq equivalent cut-off grade for zones that contain both uranium and copper mineralization (Main and Main-Lower) and at a 0.29% U3O8 Eq cut-off grade for zones that contain only uranium mineralization (Cap, Upper, Juniper I, and Juniper II). There are no Mineral Reserves estimated at the Canyon deposit at this time. Additional underground drilling conducted by the Company in 2016 and 2017 allowed for the classification of measured and indicated mineral resources, and the inclusion of a copper Mineral Resource. In October 2017, RPA estimated the Mineral Resources for both uranium and copper, shown in the following tables. 71 Canyon Mine Mineral Resources – Uranium(1)(2)(3)(4)(5)(6)(7) Zone Cut-off Grade % U3O8 Eq(8) Tons (000) Grade % U3O8 Pounds U3O8 (000) Main Main Juniper I Cap Upper Main-Lower Juniper I Juniper II 0.36 0.36 0.29 0.29 0.29 0.36 0.29 0.26 6 94 38 0.43% 0.89% 0.94% 139 0.88% --- --- 9 5 2 1 0.43% 0.20% 0.57% 0.35% 56 1,669 709 2,434 --- 78 20 25 9 18 0.38% 134 Classification Canyon Measured Resources (M) Canyon Indicated Resources (I) Total (M & I) Canyon Inferred Resources Total Inferred Resources Notes: (1) The Mineral Resource estimate in this table complies with the requirements of NI 43-101 and the classifications comply with CIM definition standards and do not represent reserves under SEC Industry Guide 7. Mineral resources that are not reserves do not have demonstrated economic viability. See “Cautionary Note to U.S. Investors Concerning Disclosure of Mineral Resources,” above. (2) For the Main and Main-Lower zones, a 0.36% uranium equivalent cut-off grade (% U3O8 Eq) was applied to account for both the copper and uranium mineralization. In all other zones only uranium was reported and a 0.29% U3O8 cut-off grade was applied. (The %U3O8 Eq grade term is not the same as the eU3O8 % grade term with indicates probe rather than assay data listed elsewhere in this report. For details see the Canyon Technical Report). (3) Mineral Resources are estimated using a long-term uranium price of US$60 per pound and a copper price of US$3.50 per pound. (4) A copper to U3O8 conversion factor of 18.19 was used for converting copper grades to equivalent U3O8 grades (U3O8 Eq) for cut-off grade evaluation and reporting for the Main and Main-Lower zones. (5) Process recoveries used were 96% for U3O8 and 90% for Cu, based on preliminary metallurgical test work. (6) Numbers may not add due to rounding. (7) Tonnages of uranium and copper cannot be added as they overlap in the Main and Main-Lower zones. (8) Note that the Tonnages of uranium and copper cannot be added as they overlap in the Main and Main-Lower zones. Canyon Mine Mineral Resources – Copper(1)(2)(3)(4)(5)(6)(7) Classification Canyon Measured Resources (M) Canyon Indicated Resources (I) Total (M & I) Zone Main Main Main Canyon Inferred Resources Main-Lower Notes: Cut-off Grade % U3O8 Eq Tons (000) Grade % Cu Pounds Cu (000) 0.36 0.36 0.36 0.36 6 94 9.29% 1203 5.70% 10,736 101 5.93% 11,939 5 5.90% 570 (1) The Mineral Resource estimate in this table complies with the requirements of NI 43-101 and the classifications comply with CIM definition standards and do not represent reserves under SEC Industry Guide 7. Mineral resources that are not reserves do not have demonstrated economic viability. See “Cautionary Note to U.S. Investors Concerning Disclosure of Mineral Resources,” above. (2) Mineral Resources are estimated at a uranium equivalent (%U3O8 Eq) cut-off grade of 0.36% U3O8 Eq. 72 (3) Mineral Resources are estimated using a long-term uranium price of US$60 per pound and a copper price of US$3.50 per lb. (4) A copper to U3O8 conversion factor of 18.19 was used for converting copper grades to equivalent U3O8 grades (U3O8 Eq) for cut-off grade evaluation and reporting. (5) Process recoveries used were 96% for U3O8 and 90% for Cu, based on preliminary metallurgical test work. (6) Numbers may not add due to rounding. (7) Tonnages of uranium and copper cannot be added as they overlap in the Main and Main-Lower Zones. Two cut-off grades were used for the resource estimate. For the uranium and copper bearing zones, a 0.36% uranium equivalent (%U3O8 Eq) cut-off grade was used. For the uranium-only zones, a 0.29% eU3O8 cut-off grade was used. The two cut-off grades account for separate process campaigns with different unit costs. Present Condition of the Property and Work Completed to Date At the Canyon Project, all surface facilities are in place. During 2017, an underground drilling program was completed, shaft sinking continued, and a large water tank was installed. As of March 8, 2018 shaft sinking had been completed. The final depth of the shaft is approximately 1,470 feet below ground surface. Shaft stations are developed at depths of 1,000 feet (elevation 5,506 feet above sea level), 1,220 feet (elevation 5,286) and 1,400 feet (elevation 5,106). Construction of the main mine sump is underway. During 2017, laboratory and bench scale metallurgical test work was carried out at the White Mesa Mill and at the Australian Nuclear Science and Technology Organization ("ANSTO"), an independent testing firm in Australia. The copper is expected to be processed using acid leach followed by solvent extraction (the same method used for uranium). Following solvent extraction, a saleable copper product is expected to be produced by either electro-winning or copper sulfate crystallization. To recover copper from the Canyon mineralized material, some modifications to White Mesa Mill process circuits are expected to be required. The copper modifications are expected to include using the existing vanadium solvent extraction circuit for copper extraction, the addition of a roaster to improve copper recovery, and the addition of either an electro-winning circuit or copper sulfate crystallization circuit. Preliminary bench test work indicates that acid leaching after roasting pre-treatment is expected to result in average copper and uranium recoveries of approximately 92% and 91% respectively. Using optimum roasting and leaching conditions, it is expected that for a continuous operation, recoveries will improve and uranium recoveries will match the nominal 96% currently experienced at the White Mesa Mill. Production copper recoveries are expected to be in the 90% range. The Canyon Project was acquired by the Company in June 2012, through the acquisition of the US Mining Division from Denison. The cost of the Canyon Project has been fully impaired, and as of December 31, 2017, the total cost attributable to the Canyon Project and its associated equipment on the financial statements of the Company was nil. The Company’s Planned Work During 2018, the Company plans to complete the construction of the main mine sump at the Canyon Project before mid-year 2018, after which time field activities will have been completed. The Company plans to continue to carry out engineering, procurement and construction management activities in 2018, including additional bench and pilot plant scale metallurgical test work of the uranium/copper mineralization, as well as pursue any additional permitting actions that may be required to recover copper at the White Mesa Mill. The timing of our plans to extract and process mineralized materials from this project will be based on the results of this additional evaluation work, along with market conditions, available financing and sales requirements. 73 The Roca Honda Project Except as noted concerning land tenure and permitting efforts, the following technical and scientific description of the Roca Honda Project is based on a technical report titled "Technical Report on the Roca Honda Project, McKinley County, State of New Mexico, U.S.A." dated October 27, 2016, prepared by Robert Michaud, P.Eng., Stuart E. Collins, P.E., and Mark B. Mathisen, C.P.G., all of Roscoe Postle Associates (“RPA”) and Harold Roberts, then Executive Vice President of the Company, in accordance with NI 43-101 (the “Roca Honda Technical Report”). The purpose of the Roca Honda Technical Report was to update the Preliminary Economic Assessment ("PEA") of the Project in light of changes in the Project ownership interest and the acquisition of additional mineral property. Each of the authors of the Roca Honda Technical Report is a “qualified person” and all but one is “independent” of the Company within the meaning of NI 43-101. Harold R. Roberts, P.E., was Executive Vice President, Conventional Operations of the Company at the time he co-authored the PEA; however, the independent authors of the Report have assumed overall responsibility for all items of the technical report, and the Report is therefore an independent technical report under NI 43-101. The Roca Honda Technical Report is available on SEDAR at www.sedar.com and on EDGAR at www.sec.gov. The Roca Honda Project does not have known reserves, and is therefore considered under SEC Industry Guide 7 definitions to be exploratory in nature, despite currently ongoing permitting activities. We acquired most of the Roca Honda Project on August 29, 2013 as a result of our acquisition of Strathmore. Certain adjacent properties (the "Adjacent Properties") (which now form part of the Roca Honda Project) were acquired from Uranium Resources, Inc. ("URI") in June 2015. 74 Property Description and Location The Roca Honda Project is an underground uranium project that is being permitted by the Company’s wholly-owned subsidiary, Strathmore Resources, U.S. Ltd. as operator of Roca Honda Resources, LLC (“RHR”). RHR was established on July 26, 2007, when Strathmore formed a limited liability company with Sumitomo and transferred the property to RHR. Strathmore purchased Sumitomo's 40% interest in RHR on May 27, 2016. The Roca Honda Project is located approximately three miles northwest of the community of San Mateo, New Mexico, near the southern boundary of McKinley County and north of the Cibola County boundary, and approximately 22 miles by road northeast of Grants, New Mexico. The property is located in the east part of the Ambrosia Lake subdistrict of the Grants Mineral Belt in northwest New Mexico and comprises nearly all of Sections 5, 6, 8, 9, 10, and a narrow strip of Section 11, the New Mexico State Lease, consisting of Section 16, and the fee mineral interest in Section 17, all in Township 13 North – Range 8 West (T13N-R8W), New Mexico Principal Meridian. Mineralized material from the Roca Honda Project will be shipped by highway truck to the White Mesa Mill, where it will be processed for the recovery of uranium. The Roca Honda Project does not have known reserves, and is therefore considered under SEC Industry Guide 7 definitions to be exploratory in nature. Accessibility, Climate, Local Resources, Infrastructure and Physiography The Roca Honda property is located approximately 17 miles (22 miles by road) northeast of Grants, New Mexico. The southern part of the property, which are on Sections 16 and 17, can be reached by traveling north from Milan, New Mexico on State Highway 605 toward the town of San Mateo to mile marker 18 and then north on a private gravel road. Access rights from Highway 605 onto Section 16 have been subject to temporary agreements with the surface owner, Fernandez Company, the latest of which expired on December 31, 2015. When the Company acquired the mineral rights to Section 17 in the URI transaction, it acquired surface access rights to Section 17 and Section 16, which the Company believes provides all necessary access. The Company is in discussions with the surface owner to determine whether any further access rights may be required. 75 The north part of the project can be reached by traveling 23.5 miles from Milan, New Mexico, on paved public Highway 605, and then west on US Forest Service roads to the southeast corner of Section 10. There are numerous drill roads that provide access to different portions of Sections 9 and 10, many of which will require maintenance. Old drill roads were previously established across the property, and an electrical line transects the northern half of Section 16 in the project area. The line continues on the west side of the project area into Section 17, where it terminates, and on the east side of Section 16 through the northwest quarter of Section 15 and along the southern section boundary of Section 10. There is a concrete lined, 14-foot diameter, 1,478-foot deep shaft, which was sunk by Kerr- McGee on Section 17 (the "Existing Shaft"). The Existing Shaft would need to be completed to a final depth of approximately 1,600 feet for use in future mine activities. No milling operations are expected to occur on the site. The climate in the Roca Honda Project area may be classified as arid to semi-arid continental, characterized by cool, dry winters, and warm, dry summers. On average, the Roca Honda property receives approximately 11 inches of precipitation annually, most of which occurs during thunderstorms in July and August. Grants, New Mexico has an annual average temperature of 50°F, with an average summer high of 87°F and low of 52°F, and average winter high of 47°F and low of 18°F. Year-round operations are expected. The community of Grants, New Mexico, located in Cibola County, is the largest community near the Roca Honda Project. As of the 2010 census, there are 8,772 people residing in Grants, where supplies can be obtained, and personnel experienced in underground mining, construction and mineral processing are available. The Roca Honda Project area is sparsely populated, rural and largely undeveloped. The predominant land uses include low density grazing and cultivation, and recreational activities such as hiking, sightseeing, and seasonal hunting. The Roca Honda property has moderately rough topography in Sections 9 and 10 and consists of shaley slopes below ledge-forming sandstone beds, as mesas, that dip 7° to 11° northeast. Elevations range from 7,100 feet to 7,800 feet. Section 9 consists mostly of steep slopes in the west and south, with a large sandstone mesa in the north central part. Section 10 consists mostly of the dip-slope of a sandstone bed that dips from 8° to 11° east. Sections 16 and 17 have less topographic relief, with elevations ranging from 7,100 to 7,300 feet and easterly dipping slopes. Vegetation in the Roca Honda Project area consists of grasses, piñon pine and juniper trees. Ownership Prior to May 27, 2016, the Roca Honda Project (excluding the Adjacent Properties) was held by RHR, a joint venture owned by Energy Fuels’ wholly-owned subsidiary Strathmore Resources, (US) Ltd. (60%) and Sumitomo’s subsidiaries SC Clean Energy and Summit New Energy Holding, LLC (together, 40%). On May 27, 2016 the Company acquired Sumitomo's 40% interest in RHR, and the Roca Honda Project is now held entirely by our wholly-owned subsidiary, Strathmore Resources, (US) Ltd. As consideration for the 40% interest, the Company issued to Sumitomo 1,212,173 common shares of the Company and agreed to pay $4.5 million of cash upon the first commercial production of uranium from the Roca Honda Project. The Adjacent Properties were acquired from URI in June 2015. The Roca Honda property covers an area of 4,440 acres, and includes 63 unpatented lode mining claims in Sections 9 and 10, 64 unpatented claims in Sections 5 and 6, 36 unpatented claims in Section 8, one adjoining New Mexico State General Mining Lease in Section 16, and the fee minerals interest in all of Section 17. The mining claims also extend onto a 9.4 acre narrow strip of Section 11. The New Mexico State Lease was acquired by David Miller (the former Strathmore CEO) on November 30, 2004, and subsequently transferred to Strathmore. Strathmore then relinquished the Lease and acquired it again in December 2015 (State Mining Lease No. HG-0133) for a new 15-year term expiring on December 14, 2030. The "Roca Honda" Claims in Sections 5 and 6 were staked by Miller and Associates in September 2004 and assigned to RHR on August 28, 2013. Strathmore acquired the Adjacent Properties, comprised of the "Roca Honda" claims in Section 8 and the fee mineral interest in Section 17 on June 26, 2015 from URI. The State Mining Lease (No. HG-0133) issued by the New Mexico State Land Office for Section 16 covers an area of 638 acres. The surface of Section 16 is leased to Fernandez as rangeland for grazing. The area covered by the Fernandez lease is also referred to as “Lee Ranch”. The Mining Lease has a primary, secondary, tertiary, and quaternary term, each with rentals to be paid in advance, and will not expire until December 14, 2030. It can be held for the next two years (primary term) by paying only $1.00 per acre annually. The State lease stipulates a 5% gross returns royalty to the State of New Mexico "less actual and reasonable transportation and smelting or reduction costs, up to 50% of the gross returns" for production of uranium, which is designated a "special mineral" in the lease. New Mexico mining and private royalties on value of minerals extracted are shown below: • • Section 9 Gross Royalty (1%); and Section 16 New Mexico State Lease Royalty (5%). Under the rights acquired in the URI transaction, a gross royalty of 1% is payable to the surface owner. 76 Permitting and Licensing The Roca Honda Project is at an advanced stage of permitting. A Draft EIS was completed by the USFS in February 2013. In March 2015 the USFS initiated the scoping process for a new mine dewatering alternative to be addressed in a Supplement to the EIS. In September 2016, an additional scoping process to incorporate Section 17 (the "Adjacent Properties") and development drilling into the mine plan was initiated by the USFS. The Supplement to the EIS is expected to be completed in 2018 with a Final EIS and Record of Decision (ROD) scheduled to be completed in 2019. Other major permits required for the Roca Honda Project include a Permit to Mine to be issued by the New Mexico Mining and Minerals Division, a Discharge Permit issued by the New Mexico Environment Department, and a Mine Dewatering Permit issued by the New Mexico State Engineer’s Office. The Mine Dewatering Permit was approved in December 2013 but appealed by the Acoma Pueblo in January 2014. RHR subsequently proposed a new alternative for discharging treated mine water that would benefit a number of downstream users including the Acoma Pueblo. As a result, the Acoma Pueblo agreed to withdraw the dewatering permit appeal in March 2015. The dewatering permit will need to be revised to reflect a higher dewatering rate with the addition of Section 17 to the mine plan. The two other major permits that are in the agency review stage are the draft Discharge Permit expected in late 2018, and the Permit to Mine expected in 2019 following approval of the Final EIS by the USFS. Permit approvals from the U.S. Army Corps of Engineers and the U.S. Environmental Protection Agency are also required for discharge of treated mine water associated with mine activities. Applications for these two permits are also presently undergoing agency review. As the project has not yet been developed or operated, we are not aware of any environmental liabilities of any significance. No permitting is required to start milling the Roca Honda Project material at the White Mesa Mill. The White Mesa Mill is fully permitted with the State of Utah, and has all the necessary operating licenses for a conventional uranium mill. As additional tailings storage capacity will eventually be required at the Mill over the life of the mine, an Amendment to the White Mesa Mill’s Radioactive Materials License issued by the Utah Division of Waste Management and Radiation Control will be required in due course to construct the next tailing cells. Geological Setting The Roca Honda Project area is located in the southeast part of the Ambrosia Lake sub-district of the Grants uranium district and is near the boundary between the Chaco slope and the Acoma sag tectonic features. This sub-district is in the southeastern part of the Colorado Plateau physiographic province and is mostly on the south flank (referred to as the Chaco slope) of the San Juan Basin. Rocks exposed in the Ambrosia Lake sub-district of the Grants Mineral Belt, which includes the Roca Honda Project area, comprise marine and non-marine sediments of Late Cretaceous age, unconformably overlying the uranium-bearing Upper Jurassic Morrison Formation. The uppermost sequence of conformable strata consists of the Mesaverde Group, Mancos Shale, and Dakota Sandstone. All rocks that outcrop at the Roca Honda Project area are of Late Cretaceous age. The uranium found in the Roca Honda Project area is contained within five sandstone units of the Westwater Canyon Member. Zones of mineralization vary from approximately one foot to 30 ft. thick, 100 ft. to 600 ft. wide, and 200 ft. to 3,000 ft. in length. Uranium mineralization in the Project area trends west-northwest, consistent with trends of the fluvial sedimentary structures of the Westwater Canyon Member, and the general trend of mineralization across the Ambrosia Lake sub-district. Core recovery from the 2007 drilling program indicates that uranium occurs in sandstones with large amounts of organic/high carbon material. Non-mineralized host rock is much lighter (light brown to light grey) and has background to slightly elevated radiometric readings. History Kerr-McGee Oil Industries, Inc. (“Kerr-McGee”) staked the Roca Honda Project unpatented mining claims in Sections 9 and 10 in June 1965. Kerr-McGee, its subsidiaries, and successor in interest Rio Algom had held the claims until the property was acquired by Strathmore on March 12, 2004. Energy Fuels acquired a 100% interest in Strathmore in September 2013, assuming Strathmore’s 60% ownership interest in RHR and becoming the project operator. Strathmore purchased Sumitomo's 40% interest in RHR on May 27, 2016. Drilling on the property began in 1966. Kerr-McGee performed a number of rotary drill hole exploration programs from 1966 to 1985. In Section 9, the first drill hole was completed in July 1966. Discovery was made in drill hole number 7 completed on August 2, 1970, 77 which encountered mineralization at a depth of 1,900 ft. From 1966 to 1982, a total of 187 drill holes were completed for a total of 388,374 ft. In Section 10, the first hole was drilled in October 1967. Discovery was made in drill hole number 6 completed on March 19, 1974, which encountered mineralization at a depth of 2,318 ft. From 1967 to 1985, a total of 175 drill holes were completed for a total of 459,535 ft. In Section 16, the first drilling was in the 1950’s by Rare Metals, which drilled 13 holes, including two that intercepted high-grade uranium mineralization at depths of 1,531 ft. and 1,566 ft. No records of the total drilled footage were located. Subsequently, Western Nuclear acquired a mining lease for Section 16 from the State and began drilling in 1968, with the first drill hole completed on August 17, 1968. The second drill hole intercepted high-grade uranium mineralization at a depth of 1,587 ft. From 1968 through September 1970, Western Nuclear drilled 63 holes totaling 121,164 feet, not including six abandoned holes totaling 7,835 ft. Two of the drill holes reported cored intervals, but the cores and analyses were not available. From the late 1960’s to the early 1980’s, a total of 725 drill holes totaling over 1,425,000 feet were completed on the six Sections (5, 6, 8, 9, 10 and 16) of the Roca Honda property. More than 500 holes totaling over 841,900 feet were also drilled in Section 17 by Kerr-McGee and Western Nuclear. In June 2015, Energy Fuels acquired a 100% interest in the mineral properties controlled by URI (Sections 8 and 17). RHR drilled four pilot holes on Section 16, of which three were completed as monitor wells totaling 8,050 feet for environmental baseline and monitoring purposes in Section 16 from June through November 2007. One drill hole was located outside of known mineralization, and three holes were located within mineralized areas. The entire thickness of the Westwater Sandstone, except for zones with no recovery, was cored in the pilot holes for these wells. The cores are PQ diameter (3.345 in.) and were taken principally for laboratory testing of hydraulic conductivity, effective porosity, density, and chemical analysis. In November 2011, a core hole was drilled at the Section 16 shaft location. The hole was drilled to a depth of 2,053 ft. Core was tested for numerous geotechnical properties. No historic mineral extraction has occurred on the property. Mineralization Uranium mineralization consists of unidentifiable organic-uranium oxide complexes. The uranium in the project area is dark grey to black in color, and is found between depths of approximately 1,450 feet and 2,600 feet below the surface. Primary mineralization pre-dates, and is not related to, present structural features. There is a possibility of some redistribution and stack mineralization along faults; however, it appears that most of the Roca Honda Project mineralization is primary. Paleochannels that contain quartz-rich, arkosic, fluvial sandstones are the primary mineralization control associated with this trend. Previous mining operations within the immediate area suggest that faults in the Roca Honda Project area associated with the San Mateo fault zone post-date the emplacement of uranium. Therefore, it may be expected that mineralized zones in the Roca Honda Project area are offset by faults. The mineralization is typically confined to sandstones in the Westwater Canyon Member, although there is some overlap into the shales that divide the sandstones, and also some minor extension (less than 10 feet) into the underlying Recapture Member. The mineralization is contained in the Westwater Canyon Member sandstones across the Project area, but in Sections 9 and 16, the mineralization is typically found in the upper sandstones (A, B1, and B2), as it is in Section 17, also. In Section 10, the A and B1 sandstones pinch out in some areas due to thickening of the overlying Brushy Basin Member. Mineralization is in the middle and western portions of Section 10, and is typically in the lower sandstones (sands C and D). Sedimentary features may exhibit control on a small scale. At the nearby Johnny M mine, a sandstone scour feature truncates underlying black mineralization, indicating nearly syngenetic deposition of uranium mineralization with the sandstone beds. Mineral Resource Estimates RPA prepared an updated PEA in 2016 and an NI 43-101 compliant Mineral Resource estimate for the Roca Honda Project is set out in the Roca Honda Technical Report. The Mineral Resource estimate, which has remained unchanged from the 2015 PEA effective as at February 4, 2015, is summarized in the following table. Mineral Resources are constrained by wireframes generated around individual mineralized zones within five sand horizons designated as A, B1, B2, C, and D sands. 78 Roca Honda Mineral Resources – Uranium(1)(2)(3)(4) Classification Roca Honda Measured Resources (M) Roca Honda Indicated Resources (I) Roca Honda Total (M & I) Roca Honda Inferred Resources Notes: Tons (000) Grade % eU3O8 Pounds eU3O8 (000) 208 0.477% 1,984 1,303 0.483% 12,580 1,511 0.482% 14,564 1,198 0.468% 11,206 (1) The Mineral Resource estimate in this table complies with the requirements of NI 43-101, and the classifications comply with CIM definition standards and do not represent reserves under SEC Industry Guide 7. Mineral resources that are not reserves do not have demonstrated economic viability. See “Cautionary Note to U.S. Investors Concerning Disclosure of Mineral Resources,” above. (2) Mineral Resources are estimated at a uranium cut-off grade of 0.19% eU3O8. (3) Mineral Resources are estimated using a long-term uranium price of US$65 per pound U3O8. (4) Numbers may not add due to rounding. Energy Fuels acquired the mineral rights to the Section 17 property adjacent to its main Roca Honda project in 2015. An historical estimate for the Section 17 property was completed by Uranium Resources Inc. (“URI”) in 2007. URI estimated that the Section 17 property contained approximately 510,000 tons at a grade of 0.37% U3O8 for 3.8 million pounds of uranium. This historical estimate is based on over 500 surface drill holes and was calculated using the circle tangent method. A density of 15 cu ft./ton was used. RPA and the Company do not consider this historical estimate to be current mineral resources or reserves as defined under NI 43-101. While Energy Fuels has reviewed all the drill hole data associated with this estimate, a qualified person has not done sufficient work to classify this historical resource as current mineral resources or mineral reserves in accordance with NI 43-101. This historical estimate was unclassified. The Company believes this historical estimate is relevant, as the methodology was well documented and utilized industry standard practice. However, the methodologies used do not reflect current best industry practices. The Company does not consider these historical estimates to be equivalent to current mineral resources or mineral reserves as defined in NI 43-101, nor has the Company completed sufficient work to confirm a NI 43-101 compliant resource. Therefore, the historical estimates cannot, and should not, be relied upon as NI 43-101 resources or reserves. Present Condition of the Property and Work Completed to Date Old drill roads were previously established across the property, and an electrical line transects the northern half of Section 16 in the project area. The line continues on the west side of the project area into Section 17, where it terminates, and on the east side of Section 16 through the northwest quarter of Section 15 and along the southern section boundary of Section 10. Three monitor water wells were drilled by RHR in 2007, and are located on Section 16. Other items installed by RHR include a permanent electrical weather station and a high volume TSP and PM10 air samplers. Three, dry man-made impoundments are also located on Section 16. More than 400 historic drill exploration holes were completed on the property from the late 1960’s to the early 1980’s. Except for the existing shaft on Section 17, there are no mine workings, existing tailings ponds, waste deposits or other improvements or facilities at the site. No additional exploration work has been conducted on the Roca Honda Project since November 2011, when a core drill hole was completed at the proposed shaft location in Section 16 for geotechnical studies. The Roca Honda Project was acquired by the Company in August 2013, through the Company’s acquisition of Strathmore. As of December 31, 2017, the total cost attributable to the Roca Honda Project on the financial statements of the Company was $22.8 million. The Company’s Planned Work The Company intends to continue its permitting and related activities at the Roca Honda Project during 2018. Approximately $0.8 million is budgeted for permitting efforts in 2018. The Company plans to integrate the Adjacent Roca Honda Properties into the permitting efforts underway for the Roca Honda Project properties. 79 The Sheep Mountain Project Unless otherwise stated (concerning land tenure and permitting efforts), the following technical and scientific description of the Sheep Mountain Project is derived from a technical report titled “Sheep Mountain Uranium Project, Fremont County, Wyoming, USA, Updated Preliminary Feasibility Study, National Instrument 43-101 Technical Report”, dated April 13, 2012 and, prepared by Douglas L. Beahm, P.E., P.G., Principal Engineer of BRS Inc. in accordance with NI 43-101 (the “Sheep Mountain Technical Report”). The author of the Sheep Mountain Technical Report is a “qualified person” and is “independent” of the Company within the meaning of NI 43-101. The Sheep Mountain Technical Report is available on SEDAR at www.sedar.com. The Sheep Mountain Project does not have known reserves, and is therefore considered under SEC Industry Guide 7 definitions to be exploratory in nature. Project Description and Location The Sheep Mountain Project is an underground and open pit uranium project. The Sheep Mountain Project was acquired on February 29, 2012, as a result of the Company’s acquisition of Titan. The Sheep Mountain Project is located eight miles south of Jeffrey City, Wyoming within the Wyoming Basin physiographic province at the northern edge of the Great Divide Basin in central Wyoming. The project is located in portions of Sections 8, 9, 15, 16, 17, 20, 21, 22, 27, 28, 29, 30, 31, 32, and 33, Township 28 North, Range 92 West. The Sheep Mountain Project includes the Congo Pit, a proposed open pit uranium extraction facility, and the reopening of the existing Sheep Underground facility. Although alternatives were considered, the recommended recovery method in the Sheep Mountain Technical Report includes the processing of extracted materials via an on-site heap leach facility. Material from the underground and open pit operations are expected to be commingled at the stockpile site located near the underground portal and in close proximity to the pit. At the stockpile, the mineralized material will be sized if needed, blended, and then conveyed via a covered overland conveyor system to the heap leach pad where it will be stacked on a double lined pad for leaching. The primary lixiviant will be sulfuric acid. Concentrated leach solution will be collected by gravity in a double lined collection pond and then transferred to the mineral processing facility for extraction and drying. The final product produced will be uranium concentrate (U3O8, also known as “yellowcake”). Since the Sheep Mountain Technical Report was completed, Energy Fuels has acquired the White Mesa Mill and the Nichols Ranch Plant, which creates the option to transport loaded resin to either of those facilities for stripping, and to the White Mesa Mill for drying, and packaging of yellowcake. 80 The preferred alternative for the development of the Sheep Mountain Project begins the operation with the open pit and heap leach facility and brings the underground component of the project into operation about five years later such that the forecasted end of extraction for both the open pit and underground components coincide. This approach defers a substantial amount of initial capital, minimizes risk, and allows for a gradual startup of site activities while maximizing resource recovery. Having the end of extraction coincide for both operations also optimizes the fixed costs of personnel and facilities. A preliminary feasibility study (“PFS”) for the project has been completed in accordance with NI 43-101, which includes the preliminary design and sequencing of the open pit and underground operations and the heap leach mineral processing facility. Designs and sequencing are inclusive of pre-production, production, and decommissioning and reclamation. The current design for the Congo Pit includes typical highwall heights in the range of 100 to 400 feet, and reaches a maximum depth of 600 feet in localized areas in the southeast pit corner. The open pit design employs similar design parameters and mining equipment configurations to those used successfully in past Wyoming conventional operations. Highwall design is based upon the performance of past projects in the Sheep Mountain and Gas Hills districts, and includes an average highwall slope of 0.7:1, which reflects the average of a 10-foot bench width and 50-foot wall at a 0.5:1 slope. The underground method proposed is also a conventional method using a modified room and pillar method, but utilizing modern equipment such as jumbo drills and 7 cubic-yard scooptrams for haulage. A new double entry decline will be constructed starting at the Paydirt Pit and ending below the deposit. Haulage from the facility will be accomplished via a 36-inch conveyor within one of the double declines. The existing shafts will be used for ventilation purposes only, with exhaust fans mounted at both locations. If the existing borehole ventilation shafts can be rehabilitated, they will be used as intake shafts. In 2013, we submitted a revised PO to the BLM, which included redesign of the heap leach processing area and the option to potentially transport the mineralized material to an off-site processing facility. The revision to the PO is expected to give us more flexibility in processing the resources extracted from the Sheep Mountain Project. A Record of Decision giving BLM's final approval of the revised PO was issued on January 6, 2017. Accessibility, Climate, Local Resources, Infrastructure and Physiography The Sheep Mountain Project is located at approximate Latitude 42°24’ North and Longitude 107° 49’ West, within the Wyoming Basin physiographic province in the Great Divide Basin at the northern edge of the Great Divide Basin. The project is approximately eight miles south of Jeffrey City, Wyoming. The nearest commercial airport is located in Riverton, Wyoming approximately 56 miles from Jeffrey City on a paved two-lane state highway. The project is accessible via 2-wheel drive on existing county and two-track roads. The Sheep Mountain Project falls within the intermountain semi-desert weather province, with average maximum temperatures ranging from 31.1 °F (January and December) to 84.9 °F (July), average minimum temperatures ranging from 9.1 °F (January) to 49.2 °F (July), and average total monthly precipitation ranging from 0.36 -inches (January) to 2.04 -inches (May). The topography consists of rounded hills with moderate to steep slopes. Elevations range from 6,600 feet to 8,000 feet above sea level. The ground is sparsely vegetated with sage and grasses and occasional small to medium sized pine trees at higher elevations. Year-round operations are contemplated for the Sheep Mountain Project. Telephone, electric and natural gas service adequate for the planned extraction and mineral processing operations have been established at the Sheep Mountain Project. Electric service and a waterline have been extended via right-of-way issued by the BLM in 2011 to the existing Sheep 1 and 2 shafts. Adequate water rights are held by the Company for planned extraction and mineral processing operations but need to be updated with the Wyoming State Engineer with respect to type of industrial use, points of diversion, and points of use. We believe that sufficient surface rights are in place for all contemplated operations, including tailings storage areas, waste disposal, heap leach pads, and potential processing sites. Ownership The mineral properties at the Sheep Mountain Project are comprised of 192 unpatented mining claims (the Company added 13 claims to the 179 reported in the Sheep Mountain Technical Report) on land administered by the BLM; approximately 640 acres of State of Wyoming leases; and approximately 630 acres of private leases on fee lands. In February 2012, Energy Fuels purchased 320 acres of private surface overlaying some of the federal minerals covered by 18 of the claims. The purchased parcel includes the SW¼ SW¼ Section 28 and SE¼, E½ SW¼, and NW¼ SW¼ Section 29, T28N, R92W. A final payment of $5,000 was made in January 2016 for the purchased parcel. The combination of land holdings (including the 13 new claims) comprises approximately 4,675 acres and gives Energy Fuels mineral rights to resources as defined in the Congo Pit and the Sheep Underground areas. After the 2012 Technical Report, the Company increased the Sheep Mountain property size by 26 unpatented mining claims (approximately 520 acres) through the 81 acquisition of Strathmore. These contiguous claims form a larger buffer, with potential for additional uranium resources, along the west side of the Project. To maintain these mineral rights, the Company must comply with the lease provisions, including annual payments with respect to the State of Wyoming leases; private leases; BLM and Fremont County, as well as Wyoming filing and/or annual payment requirements to maintain the validity of the unpatented mining lode claims as follows. Mining claims are subject to annual filing requirements and payment of a fee of $155 per claim. Unpatented mining claims expire annually, but are subject to indefinite annual renewal by filing appropriate documents and paying the fees described above. ML 0-15536 will expire on 1/1/2024. Annual Payments to maintain ML 0-15536 are $2,560 per year. The original private lease dated November 20, 2975 between McIntosh Cattle Company and Western Nuclear Inc. (the “Private Lease”) expired 11/20/2015. Properties covered by the Private Lease include: Township 28 North, Range 92 West, 6th PM; Section 20: S½SW¼; Section 29: NW¼, SW¼SW¼; Section 30: SE¼NE¼, E½SE¼; Section 31: E½NE¼; Section 32: E½NE¼; Section 33: S½NW¼. Since the date of the Sheep Mountain Technical Report, the Company no longer holds the Private Lease, however a Surface Owner’s Agreement (originally dated January 27, 1970, as amended on April 14, 1981 and ratified by assignees on April 16, 2007) covering the same parcels and a few select claims in the Sun-Mc area is still in effect. It carries a 2% mine value royalty for any material extracted from the subject lands, but no other payment obligations. The Sheep Mountain Project is subject to an overall sliding scale royalty of 1% to 4% due to Western Nuclear, based on the Nuclear Exchange Corporation Exchange (“NUEXCO”) Value. This royalty is currently at its maximum rate of 4%. Under Wyoming State Lease ML 0-15536, there is a royalty of 5% of the quantity or gross realization value of the U3O8, based on the total arms-length consideration received for uranium products sold. Uranium mining in Wyoming is subject to both a gross products (county) and mineral severance tax (state). At the federal level: aggregate corporate profit from mining ventures is taxable at corporate income tax rates, i.e. individual mining projects are not assessed federal income tax but rather the corporate entity is assessed as a whole. For mineral properties: depletion tax credits are available on a cost or percentage basis whichever is greater. The percentage depletion tax credit for uranium is 22%, among the highest for mineral commodities, IRS Pub. 535. Permitting and Licensing In June 2010, Titan commenced baseline environmental studies to support an application to the NRC for a Source Material and By- product Material License (the “License”) for operation of a heap leach facility. Work was also initiated on a revision to the existing WDEQ Mine Permit, as well as a PO for the BLM. Baseline studies included wildlife and vegetation surveys, air quality and meteorological monitoring, ground and surface water monitoring, radiological monitoring, and cultural resource surveys. Submission of the PO to the BLM was made in June 2011. The PO was accepted as complete by the BLM, and an EIS was initiated in August 2011. Energy Fuels revised the PO in July 2012, consistent with the modified plan presented in the Sheep Mountain Technical Report. In July 2013, the PO was again revised to reflect a new waste rock disposal layout for the open pit mine and an improved and more economical heap leach and processing facility. The revised PO also included the option of transporting mineralized material off- site for processing. The Final EIS was completed in August of 2016. On January 6, 2017, the BLM issued its RoD and approved the PO. In October 2011, Titan submitted a draft revision to its existing Mine Permit 381C to WDEQ. WDEQ then provided Titan with review comments as part of its “courtesy review.” The permit revision was revised and resubmitted in January 2014. In July 2015, the revision was approved by WDEQ. The revision includes expansion of surface and underground mining operations and an updated reclamation plan consistent with current reclamation practices. Development of an application to the NRC for a license to construct and operate the uranium recovery facility has been taken to an advanced stage of preparation. This license would allow Energy Fuels to process the mineralized material into yellowcake at the Sheep Mountain Project site. The draft application to NRC for a Source Material License was reviewed in detail by the NRC in October 2011. The NRC audit report identified areas where additional information should be provided. The review and approval process for this license by the NRC is anticipated to take approximately four years from the date submitted to the NRC. Submittal of the license application to the NRC is on hold pending the Company’s evaluation of off-site processing options for this project, and if a decision is made to proceed with an on-site uranium recovery facility, pending improvements in uranium market conditions. The heap leach facility has been permitted through the State of Wyoming and BLM, yet still requires NRC licensing. The permitted capacity is 4 million tons of mineralized material which is 53% of the NI 43-101 Mineral Reserves declared. An expansion to the heap leach facility (including permitting) will be required in the future to process the remaining 47% of the 43-101 Mineral Reserves. 82 Geological Setting A primary component of the geology for the Sheep Mountain Project is the Battle Spring Formation. Battle Spring is Eocene in age. Prior to deposition of the Battle Spring Formation and subsequent younger Tertiary formations, underlying Paleocene, Cretaceous, and older formations were deformed during the Laramide Orogeny. During the Laramide Orogeny, faults, including the Emigrant Thrust Fault at the northern end of the project area, were active and displaced sediments by over 20,000 feet. Coincident with this mountain building event, Paleocene and older formations were folded in a series of echelon anticlines and synclines, generally trending from southeast to northwest. The Battle Spring Formation was deposited unconformably on an erosional landscape influenced by these pre- depositional features. Initial stream channels transporting clastic sediments from the Granite Mountains formed in the synclinal valleys. The geologic setting of the Sheep Mountain Project is important in that it controlled uranium mineralization by focusing movement of the groundwaters, which emplaced the uranium into the stream channels, which had developed on the pre-tertiary landscape. The Battle Spring Formation and associated mineralization at the Sheep Mountain Project is bounded to the east by the western flank of the Sheep Mountain Syncline and to the west by the Spring Creek Anticline. To the north the system is cut off by erosion. To the south the Battle Spring continues into the northern portions of the Great Divide Basin. Mineralization occurs throughout the lower A Member of the Battle Spring Formation and is locally up to 1,500 feet thick. The upper B Member is present only in portions of the project and may be up to 500 feet thick. Although arkosic sandstone is the preferred host, uranium has been extracted from all lithologies. Grade and thickness are extremely variable depending on whether the samples are taken from the nose or the tails of a roll front. Typically the deposits range from 50 feet to 200 feet along a strike, five feet to eight feet in height, and 20 feet to 100 feet in width. Deposits in the Sheep Mountain Project area occur in stacked horizons from 7,127 feet in elevation down to 6,050 feet in elevation. History The Sheep Mountain Project was acquired by Energy Fuels on February 29, 2012, as a result of the Company’s acquisition of Titan, which is now a wholly owned subsidiary of Energy Fuels. Titan acquired the Sheep Mountain Project in two transactions in 2009. A 50% working interest was acquired when Titan completed a business combination with Uranium Power Corp. (“UPC”) on July 31, 2009. UPC is now a wholly-owned subsidiary of Energy Fuels. At that time, UPC and UPC’s US subsidiary (then called UPC Uranium (USA) Inc. and now called Energy Fuels Wyoming Inc.) became wholly-owned subsidiaries of Titan. The remaining 50% of the Sheep Mountain Project was owned by Uranium One Inc. (“U1”) which was UPC’s joint venture partner for the project. On October 1, 2009, Titan acquired U1’s 50% interest, giving Titan a 100% interest in the Sheep Mountain Project. On February 29, 2012, Energy Fuels acquired Titan (and its subsidiaries) at which point the Sheep Mountain Project became 100% owned by the Company. The Sheep Mountain Project was operated as an underground and open pit mine at various times in the 1970’s and 1980’s. 5,063,813 tons of mineralized material were mined and milled, yielding 17,385,116 pounds of uranium at an average grade of 0.17% U3O8. Mining was suspended in 1988 and the project has been on care and maintenance since that time. Uranium was first discovered in the Crooks Gap District, which includes the Sheep Mountain Project, in 1953. While the original discoveries were aided by aerial and ground radiometric surveys, exploration activities were primarily related to drilling and exploratory trenching. Three companies dominated the district by the mid-1950s: Western Nuclear Inc. (“Western Nuclear”), Phelps Dodge Corporation (“Phelps Dodge”), and Continental Uranium Corporation (“Continental”). Western Nuclear built the Split Rock mill at Jeffrey City in 1957 and initiated production from the Paydirt pit in 1961, Golden Goose 1 in 1966, and Golden Goose 2 in 1970. Phelps Dodge was the principal shareholder and operator of the Green Mountain Uranium Corporation’s Ravine Mine, which began production in 1956. Continental developed the Seismic Pit in 1956, the Seismic Mine in 1957, the Reserve Mine in 1961, and the Congo Decline in 1968. In 1967, Continental acquired the Phelps Dodge properties and in 1972, Western Nuclear acquired all of Continental’s Crooks Gap holdings. During the mid-1970’s Phelps Dodge acquired an interest in Western Nuclear, which began work on the Sheep Mountain I in 1974, the McIntosh Pit in 1975, and Sheep Mountain II in 1976. Western Nuclear ceased production from the area in 1982. Western Nuclear production from the Sheep Mountain I is reported to have been 312,701 tons at 0.107% U3O8. Subsequent to the closure of the Sheep Mountain I by Western Nuclear, during April to September 1987, Pathfinder Mines Corporation (“Pathfinder”) mined a reported 12,959 tons, containing 39,898 pounds of uranium at an average grade of 0.154% U3O8 from Sheep Mountain I. U.S. Energy-Crested Corp. (“USECC”) acquired the properties from Western Nuclear in 1988, and during May to October 1988, USECC mined 23,000 tons from Sheep Mountain I, recovering 100,000 pounds of uranium for a mill head grade of 0.216% U3O8. The material was treated at Pathfinder’s Shirley Basin mill, 130 miles east of the Project. The Sheep Mountain I mine was allowed to flood in April 2007. UPC (then known as Bell Coast Capital) acquired a 50% interest in the property from USECC in late 2007. USECC later sold all of its uranium assets to U1. Titan acquired UPC’s 50% interest in the property when it acquired UPC by a plan of arrangement in July 2009. Titan acquired U1’s interest in the Sheep Mountain Project in September 2009. 83 During the National Uranium Resource Evaluation (“NURE”) program conducted by the DOE in the late 1970’s and early 1980’s, the project area and vicinity were evaluated. This evaluation included aerial gamma, magnetic, and gravimetric surveys, soil and surface water geochemical surveys and sampling, and geologic studies and classification of environments favorable for uranium mineralization. Approximately 4,000 holes were drilled in the project area historically (prior to 1988), most of which were open-hole rotary drilling, reliant upon down-hole geophysical logging to determine equivalent uranium grade % eU3O8. However, some core drilling for chemical analysis was also completed. The drill maps show hole locations at the surface and downhole drift, the thickness and radiometric grade of uranium measured in weight percent U3O8, elevation to the bottom of the mineralized intercept, collar elevation, and elevation of the bottom of the hole. In 2006, UPC completed a drilling program consisting of 19 holes totaling 12,072 feet. Two of the 19 holes were located in Section 28 with the purpose of confirming the mineralization within the Sheep Underground mine area. The remaining 17 holes were completed in the planned Congo Pit to test both shallow mineralization and to explore a deeper mineralized horizon. This 2006 drilling has confirmed the presence of mineralization in the shallow horizons of the Congo Pit area and has identified and extended roll front mineralization in the 58 sand along strike. Following the acquisition of UPC by Titan, five holes were drilled in the Congo Pit area in 2009 for a total of 1,700 feet. In situ mineral grades for 2009 drilling were determined by geophysical logging including both conventional gamma logging and state of the art Uranium Spectrum Analysis Tool. Titan also drilled in the Congo Pit area in 2010 62 exploratory drill holes and 5 monitor wells and 2011 73 exploratory drill holes and 5 monitor wells. There were a total of 140 exploration holes drilled between 2009 and 2011, which total about 44,000 feet. No relevant exploration work other than this drilling has been conducted on the property in recent years. The project is located within a brownfield site, which has experienced past mine production and extensive exploration and development drilling. The initial discovery was based on aerial and ground radiometric surveys in the 1950s, but since that time exploratory work on the site has been primarily drilling. Mineralization Most of the mineralization in the Crooks Gap District occurs in roll-front deposits. Roll fronts have an erratic linear distribution but are usually concordant with the bedding. Deposits have been discovered from the surface down to a depth of 1,500 feet. The two major uranium minerals are uranophane and autunite. Exploration drilling indicated that the deeper roll-type deposits are concentrated in synclinal troughs in the lower Battle Spring Formation. Three possible sources for uranium have been suggested: post-Eocene tuffaceous sediments, leached Battle Spring arkoses, and Precambrian granites. Structural controls of uranium occurrences along roll fronts include carbonaceous siltstone beds that provide a local reducing environment for precipitation of uranium-bearing minerals, and abrupt changes in permeability along faults, where impermeable gouge is in contact with permeable sandstones. Uranium has also been localized along the edges of stream channels and at contacts with carbonaceous shales. Mineral Resources Mineral Resource and Mineral Reserve Estimates The Mineral Resource estimates for the Sheep Mountain Project are summarized in the following table. The Mineral Resource estimates presented herein have been completed in accordance with CIM Standards and NI 43-101. Based on the drill density, the apparent continuity of the mineralization along trends, geologic correlation and modeling of the deposit, a review of historic mining with respect to current resource projections, and verification drilling, the Mineral Resource estimate herein meets CIM criteria as an Indicated Mineral Resource. These Indicated Mineral Resources are not reserves within the meaning of SEC Industry Guide 7. See Cautionary Note to U.S. Investors Concerning Disclosure of Mineral Resources, above. Below is a summary of the total Indicated Mineral Resources(1) estimated for the Sheep Mountain Project: 84 Sheep Mountain Mineral Resources – Uranium(1)(2)(3) Classification Sheep Mountain Measured Resources (M) Zone --- Sheep Underground Congo Pit Area Sheep Mountain Indicated Resources (I) Sun-Mc Total (M & I) G.T. Cut-off Tons (000) Grade % eU3O8 Pounds eU3O8 (000) --- 0.30 0.10 0.10 --- --- --- 5,640 0.117% 13,245 6,176 0.122% 15,040 1,080 0.093% 2,000 12,895 0.117% 30,285 Sheep Mountain Inferred Resources --- --- --- --- --- Notes: (1) The Mineral Resource estimate in this table complies with the requirements of NI 43-101 and the classifications comply with CIM definition standards and do not represent reserves under SEC Industry Guide 7. Mineral resources that are not reserves do not have demonstrated economic viability. See “Cautionary Note to U.S. Investors Concerning Disclosure of Mineral Resources,” above. (2) Mineral Resources are estimated at a uranium grade x thickness (G.T.) cut-off grade of 0.10 G.T. (2 ft. of 0.05% eU3O8 for the Congo Pit and Sun-Mc areas and 0.30 G.T. (6 ft. of 0.05% eU3O8) for the Sheep Underground. (3) Numbers may not add due to rounding. This estimate includes deletion of the portions of the mineral resource model which falls within the historic limits in the Congo Pit estimated to have removed some 25% of the initial resource estimate and the total reported mined tonnage from the historic Sheep I underground mine. From review of the Sheep I and II as-built mine plans, it was apparent that little or no mineralized material was mined at the historic Sheep II and that only development work was completed. Historic underground mining in the Sun Mc area is estimated to have removed some 10% of the total resource. Although in many cases the mine maps showed remnant pillars, none of these areas were included in the mineral resource estimate. Thus, the estimate of current mineral resources is conservative with respect to the exclusion of areas affected by historic mining. Estimated mineral resources for potential open pit areas were diluted to a minimum mining thickness of two feet and a cutoff grade of 0.05% U3O8, which equates to a 0.10 GT cutoff. The cutoff of 0.10 GT used for estimating the Mineral Resources for the open pit areas is the same cutoff value as that used for estimating the Mineral Reserves at a $65/Lb uranium price. The cutoff of 0.30 GT used for estimating the Mineral Resources for Sheep Underground is lower than the 0.45 GT cutoff used for estimating the Mineral Reserves at a $65/Lb uranium price. Some of the Mineral Resources fall outside of the mine plan, whereas all of the Mineral Reserves fall within the mine plan. Mineral Reserves The estimate of mineral reserves for the Sheep underground extraction area is set out in the Sheep Mountain Technical Report. With respect to the open pit mineral reserves, mineral resources for the Congo, North Gap, and South Congo areas were combined into a single comprehensive mineral resource model. Open pit mine designs and sequencing was completed for all areas, and the resultant mineral reserve estimate reflects the current open pit mine designs and economic evaluations. These reserves have been calculated in accordance with NI 43-101 and should not be considered to meet the definition of reserves within the meaning of SEC Industry Guide 7. Resources that are not reserves do not have demonstrated economic viability. See Cautionary Note to U.S. Investors Concerning Disclosure of Mineral Resources, above. Below is a summary of the total Probable Mineral Reserve estimate for the Sheep Mountain Project as calculated in accordance with NI 43-101: 85 Sheep Mountain Mineral Reserves – Uranium(1)(2)(3)(4) Classification Sheep Mountain Proven Reserves Sheep Mountain Probable Reserves Total Proven and Probable Reserves Notes: Zone --- Open Pit Underground G.T. Cut-off Tons (000) Grade % eU3O8 Pounds eU3O8 (000) --- 0.10 0.45 --- --- 3,955 0.115% 3,498 0.132% --- 9,117 9,248 7,453 0.123% 18,365 (1) The Mineral Reserve estimate in this table complies with the requirements of NI 43-101 and the classifications comply with CIM definition standards and do not represent reserves under SEC Industry Guide 7. (2) Mineral Reserves are estimated at a uranium grade x thickness (G.T.) cut-off grade of 0.10 G.T. (2 ft. of 0.05% eU3O8) for the Congo Pit and 0.45 G.T. (6 ft. of 0.075% eU3O8) for Sheep Underground. (3) Mineral Reserves are estimated using a long-term uranium price of US$65 per pound U3O8. (4) Numbers may not add due to rounding. The Probable Mineral Reserves are fully included in the total Indicated Mineral Resources for the Congo Pit and are not additive to that total. The Probable Mineral Reserve is that portion of the Indicated Mineral Resource that is economic under estimated costs and assumed pricing conditions. The cutoff grade of 0.075% eU3O8 at a minimum mining height of 2 foot equates to a 0.10 GT cutoff for the Congo Pit. The cutoff grade of 0.075% eU3O8 at a minimum mining height of 6 feet equals a 0.45 GT cutoff used for the Sheep underground extraction area. The cutoff grade was determined based on an assumed uranium price of $65 per pound U3O8. Present Condition of the Property and Work Completed to Date The Sheep Mountain Project includes the Congo Pit, a proposed open pit uranium extraction facility, and the reopening of the existing Sheep Underground mining facility. Mineral Extraction at the Sheep Underground mining facility was suspended in 1988 and the project has been on care and maintenance since that time. The Sheep Mountain Project does not currently have a processing facility. Transportation of mineralized materials to the White Mesa Mill is not economic at current or foreseeable uranium price levels. As a result, it will be necessary to permit and construct a heap leach or other processing facility at the site, or make arrangements to process Sheep Mountain mineralized materials at a third party processing facility. The Company is subject to liabilities for mine reclamation at the Sheep Mountain project. The Company maintains a bond in the amount of $950,000 with the State of Wyoming as security for these liabilities. The Company files an annual report with the State of Wyoming, and the amount of the bond may be adjusted annually to ensure sufficient surety is in place to cover the full cost of reclamation. The Company’s reclamation of the exploration drilling performed by Titan was deemed complete in October 2014; the drilling permit was terminated and that bond was fully released. The Sheep Mountain Project was acquired by the Company in February 2012, through the Company’s acquisition of Titan. As of December 31, 2017, the total cost attributable to the Sheep Mountain Project on the financial statements of the Company was $34.18 million. The Company’s Planned Work The Company will continue to evaluate its options for processing Sheep Mountain mineralized material, including continuing to pursue permitting for a heap leach facility at the site, evaluating other types of processing facilities at the site, or determining whether arrangements can be made to process Sheep Mountain mineralized materials at a third party processing facility. Submittal of the license application to the NRC for a heap leach processing facility at the site is on hold pending the Company’s evaluation of off-site processing options for this project. The project is currently on standby, pending completion of the evaluation of the processing options for the Project and improvement in market conditions. 86 The Henry Mountains Complex Except as noted below concerning the land and permitting efforts, the following technical and scientific description of the Henry Mountains Complex is based on the technical report dated June 27, 2012 titled “Technical Report on the Henry Mountains Complex Uranium Property, Utah, U.S.A.”, prepared by William E. Roscoe, Ph.D., P.Eng., Douglas H. Underhill, Ph.D., C.P.G. and Thomas C. Pool, P.E. of Roscoe Postle Associates Inc. (“RPA”) in accordance with NI 43-101 (the “Henry Mountains Technical Report”). Each of the authors of the Henry Mountains Technical Report is “independent” of Energy Fuels and a “qualified person” for purposes of NI 43-101. The report contains mineral resource estimates for the Indian Bench, Copper Bench, Southwest and Tony M deposits. The Henry Mountains Technical Report is available on SEDAR at www.sedar.com and on EDGAR at www.sec.gov. The Henry Mountains Complex does not have known reserves, and is therefore considered under SEC Industry Guide 7 definitions to be exploratory in nature, despite uranium extraction activities occurring at the Tony M deposits as recently as 2008. Property Description and Location The Henry Mountains Complex is an underground project comprised of the Bullfrog Property, hosting the Indian Bench and the Copper Bench deposits, and the Tony M Property, hosting the Southwest deposit and the Tony M deposit and associated mineral extraction facilities. The Henry Mountains Complex is located in eastern Garfield County, Utah. 87 Accessibility, Climate, Local Resources, Infrastructure and Physiography Road access to the Henry Mountains Complex is by paved Highway 276, running between Hanksville and Bullfrog Basin Marina, Utah. An unimproved gravel road maintained by Garfield County extends west from Highway 276, passes by the portal of the Tony M Property, and extends northerly across the property, the northern end of which is crossed by another county road. The property is located in a relatively remote area of Utah, and the infrastructure is limited. The town site of Ticaboo, Utah, is located approximately five miles south of the property. Ticaboo has been used to provide housing and municipal services for Tony M Property staff. The next closest community is Hanksville, Utah, a small town of a few hundred people, located about 40 miles north of the property. During operation of the Tony M Property, electricity was generated locally. Materials and supplies are transported to the site by truck about 275 miles from Salt Lake City, and about 190 miles from Grand Junction, Colorado. The distance to the White Mesa Mill is about 117 miles. The climate is distinctly arid, with an average annual precipitation of approximately eight inches, including about 12 inches of snow. The vegetation consists primarily of small plants including some of the major varieties of blackbrush, sagebrush, and rabbit brush. A few small junipers are also present. Relief over the combined Henry Mountains Complex is approximately 2,250 feet (the technical report erroneously reported 800 feet). The elevation on the property ranges from 4,550 ft. above sea level at the portal of the Tony M Property, near the southern end of the property, to 6,800 ft. above sea level over the northern end of the property. The terrain is typical canyon lands topography, with some areas deeply dissected by gullies and headwalls of canyons and the rest consisting of gently undulating gravel benches covering the northern part of the project area. The terrain in several parts of the property is particularly rugged and inaccessible and is the primary reason for the irregular pattern of surface drill holes in parts of the property. 88 Ownership The Henry Mountains Complex is 100% owned by Energy Fuels, and was acquired from Denison Mines Corp. and its affiliates in June 2012. The project consists of one Utah State Mineral Lease for Section 16, Township 35 South, Range 11 East (T35S R11E), Salt Lake Meridian (SLM), and 202 unpatented federal lode mining claims. The latter consist of 137 B.F., 19 Bull, 19 Star, two Frog claims (comprising the Bullfrog Property), and 17 TIC and eight Ticaboo claims, including fractions (comprising the Tony M property). The claims and state lease comprise one contiguous property located in T34S, R11E and T35S, R11E, SLM. The Utah State Section 16 includes 638.54 acres, and the 202 unpatented lode mining claims consist of about 3,667.18 acres (not specified in the technical report), for a total land holding of 4,305.72 acres. The surface rights are owned by the federal government, administered by the BLM, with the exception of the State lease, which has associated state surface rights. There is no royalty burden for the 185 claims that comprise the Bullfrog Property, as well as for the Ticaboo claims. All unpatented mining claims are subject to an annual federal mining claim maintenance fee of $155 per claim plus approximately $10 per claim for county filing fees. The 17 TIC claims are held by Energy Fuels, subject to an annual advance minimum royalty. The uranium production royalty burden is 4% yellowcake gross value less taxes and certain other deductions. The vanadium production royalty burden is 2% gross value less certain deductions. The Utah State Lease carries an annual rental of $640, plus an escalating annual advance minimum royalty based on the uranium spot price. Since the technical report was written, the State lease was renewed in 2015 for an additional 10-year term, which can be extended. Other changes in the renewed lease include reducing annual advanced royalty payments and crediting the advanced royalty against the production royalty for the year in which it is paid plus any amount paid in the five prior years. The uranium royalty on the State lease is 8% of gross value less certain deductions. The vanadium royalty on the State lease is 4% of gross value less certain deductions. Tony M Property: Permitting The original Tony M Property mine permit was allowed to lapse. Subsequently the previous operator, Denison, filed for exploration permits with the Utah Division of Oil, Gas and Mining (“UDOGM”) and the BLM. These permits were granted by UDOGM and the BLM on December 2, 2005 and March 6, 2006, respectively, which enabled Denison to regain access, inspect and begin rehabilitation of the Tony M underground workings. Denison also began the permitting process for the Tony M Property. The permit application was submitted in November 2006 and a RoD and approved PO were received in September 2007. The PO was challenged by the Center for Water Advocacy and the Utah Chapter of the Sierra Club, which requested a Utah State BLM Director Review and a stay of the decision approving the Final PO for the Tony M Property. On November 21, 2007, the BLM State Director issued a decision vacating the previously issued permit and remanded the case to the Field Office in order that the EA for the Tony M Mine PO could be amended and a new RoD issued. As a result of this decision to vacate and renew, the request for stay was considered moot. The new decision was issued by the BLM on November 23, 2007 approving the PO for the project. The new decision was once again appealed by the Center for Water Advocacy and the Utah Chapter of the Sierra Club. The Utah State Director issued a decision denying the appeal and upholding the PO on February 19, 2008. In addition to the PO and FONSI from the BLM, major permits for the Tony M property include an approved Large Mine permit with UDOGM, and an approved ground water discharge permit with the Utah Division of Water Quality (“DWQ”). A reclamation bond of $708,537 is in place. Permit applications for a Phase 2 expansion were submitted to the BLM and UDOGM in 2008, but Denison subsequently requested that BLM and UDOGM review of the applications be deferred given the market conditions at that time. Bullfrog Property: The Company is currently completing environmental baseline studies and preparing mine plans for permitting purposes at the Bullfrog Property. An Exploration Notice of Intent was submitted to UDOGM and BLM in late 2016 to allow for drilling of 23 holes planned as offset/confirmation data and a few to be core holes to gather geotechnical and metallurgical information. The NOI has not been approved by DOGM and approval by BLM is pending additional information. Geologic Setting Exposed rocks in the project area are Jurassic and Cretaceous in age. Host rocks for the Copper Bench-Indian Bench and Tony M- Southwest uranium-vanadium deposits are Upper Jurassic sandstones of the Salt Wash Member of the Morrison Formation. This formation is located within the Colorado Plateau. Early Tertiary fluvial and lacustrine sedimentation within the deeper parts of local basins was followed in mid-Tertiary time by laccolithic intrusion and extensive volcanism. Intrusions of diorite and monazite porphyry penetrated the sediments at several sites to form the laccolithic mountains of the central Colorado Plateau. 89 The Morrison Formation is a complex fluvial deposit of Late Jurassic age. In outcrop, the Salt Wash is exposed as one or more massive, ledge-forming sandstones, generally interbedded with laterally persistent siltstones or mudstones. The lower Salt Wash is approximately 150 ft. thick in the Project area, thinning and becoming less sandy northward from the project area. Sandstones comprise 80% of the sequence, with siltstones and mudstones making up the remainder. Significant uranium mineralization occurs only in this lower unit. History In 1970 and 1971, Rioamex Corporation conducted a 40-hole drilling program in an east-west zone extending across the southerly end of the Bullfrog Property and the northerly end of the Tony M and adjacent Frank M properties. Some of these holes intercepted significant uranium mineralization. The Bullfrog deposit was initially explored by Exxon Minerals Company (“Exxon”), while the Tony M deposit was explored and advanced by Plateau Resources Ltd. (“Plateau”), a subsidiary of Consumers Power Company (“Consumers”) of Michigan. In February 1977, drilling commenced in what was to become the Tony M deposit. Subsequently, Plateau drilled more than 2,000 rotary drill holes totaling about 1,000,000 feet. Over 1,200 holes were drilled in the Tony M area. Following the discovery of the Tony M deposit in 1977, Plateau developed the Tony M Property from September 1, 1977, to about May 1984, at which time mining activities were suspended. By January 31, 1983, over 18 miles of underground workings were developed at the Tony M Property, and a total of approximately 237,000 tons of mineralized material was extracted with an average grade of 0.121% U3O8 containing about 573,500 pounds U3O8. The underground workings at the Tony M Property are accessed via two parallel declines extending about 10,200 ft. into the deposit. The underground workings were allowed to flood after mining activities were suspended in 1984. The southern one-half of the underground workings remained dry, as they are located above the static water table. Exxon commenced drilling on the Bullfrog Property in 1977. Before it sold the property to Atlas in July 1982, Exxon had drilled 1,782 holes. From July 1982 to July 1983, Atlas completed 112 drill holes delineating the Southwest and Copper Bench deposits on approximately 100 ft. centers. After July 1983, Atlas completed an additional 49 core hole drilling program throughout the Bullfrog Property, as well as a 133 rotary drill hole program to delineate the Indian Bench deposit on approximately 200 ft. centers. 2,232 drill holes were completed on the Bullfrog Property. The Southwest and Copper Bench deposits are delineated by drilling on approximately 125-foot centers. The Indian Bench deposit is delineated by drilling on approximately 200 ft. centers. In some areas, the rugged terrain made access difficult, resulting in an irregular drill pattern. Records indicate that 81 core holes were drilled in the Southwest, Copper Bench, and Indian Bench deposits, while 25 core holes were drilled in the vicinity of the Tony M deposit. The core holes provided samples of the mineralized zone for chemical and amenability testing. Denison acquired the Bullfrog Property when it purchased most of the assets of EFN in 1997. In February 2005, Denison acquired the Tony M Property bringing it under common ownership with the Bullfrog Property. Following rehabilitation work at the Tony M Property and re-establishment of surface facilities in 2006, Denison received operational permits, reopened the Tony M underground workings and commenced mining activities in September 2007. This work included a long-hole drilling program to discover and delineate mineralization within about 100 feet of underground workings. In November 2008, Denison announced that mining activities at the Tony M Property would be suspended due to uranium and economic market conditions. During its September 2007 to December 2008 reactivation, cleanup and mining activities, Denison extracted 162,384 tons of mineralized material at radiometric grade of 0.131% containing 429,112 pounds U3O8 from within existing workings and from the previously stockpiled material. This material was trucked to the White Mesa Mill for processing. In June 2012, Energy Fuels acquired all of Denison’s uranium properties in the United States, including the Henry Mountains Complex. No mine development has been conducted on the Southwest portion of the Tony M-Southwest deposit or on the Copper Bench-Indian Bench deposit located further north. Energy Fuels has carried out no exploration work on the Henry Mountains Complex. Mineralization Uranium mineralization in the Henry Mountains Complex is hosted by favorable sandstone horizons containing detrital organic debris. Mineralization primarily consists of coffinite, with minor uraninite, which usually occurs in close association with vanadium mineralization. Mineralization occurs as intergranular disseminations, as well as coatings and/or cement on and between sand grains and organic debris. Vanadium occurs as montroseite (hydrous vanadium oxide) and vanadium chlorite in primary mineralized zones located below the water table (i.e., the northern portion of the Tony M deposit). Historic production records from the AEC for the South 90 Henry Mountains district suggest that the vanadium content of the district is relatively low. Based on the review of the available analyses, RPA is of the opinion that the V2O5:U3O8 ratio ranges from about 1.3:1 to about 2.0:1 in the Henry Mountains Complex deposits. The Henry Mountains Complex vanadium-uranium deposits consist of two extensive elongate, tabular zones containing a large concentration of mineralization. The Tony M–Southwest deposit extends for a distance of approximately 2.5 miles along a north-south trend and has a maximum width of about 3,000 ft. The larger Copper Bench-Indian Bench deposit extends approximately 3.5 miles along a northwesterly trend to the northeast of the Tony M–Southwest deposit. Mineral Resource Estimates Mineral Resources of the Tony M-Southwest deposit were estimated by Denison in 2009 using the GT contour method, and Mineral Resources of the Copper Bench-Indian Bench deposit were estimated in 1993 by EFN using the polygonal block method. These Mineral Resources are not reserves within the meaning of SEC Industry Guide 7. Henry Mountains Complex Mineral Resources – Uranium(1)(2)(3)(4) Classification Henry Mountains Measured Resources (M) Henry Mountains Indicated Resources (I) Total (M & I) Henry Mountains Inferred Resources Total Inferred Resources Notes: Zone --- Tony M(2) Southwest(2) Indian Bench(3) Copper Bench(3) Tony M(2) Southwest(2) Indian Bench(3) Copper Bench(3) Tons (000) Grade % eU3O8 Pounds eU3O8 (000) --- --- 1,030 0.24% 660 220 500 0.25% 0.40% 0.29% --- 4,830 3,300 1,740 2,930 2,410 0.27% 12,800 650 210 250 500 0.17% 0.14% 0.42% 0.32% 1,610 0.25% 2,170 580 2,090 3,240 8,080 (1) The Mineral Resource estimate in this table complies with the requirements of NI 43-101 and the classifications comply with CIM definition standards and do not represent reserves under SEC Industry Guide 7. Mineral resources that are not reserves do not have demonstrated economic viability. See “Cautionary Note to U.S. Investors Concerning Disclosure of Mineral Resources,” above. (2) Mineral Resources for Tony M and Southwest are estimated at a uranium grade x thickness (G.T.) cut-off of 0.20 G.T. (2 ft. of 0.10% eU3O8). This cut-off is estimated using a long-term uranium price of US$60 per pound U3O8. (3) Mineral Resources for Indian Bench and Copper Bench are estimated at a uranium grade x thickness (G.T.) cut-off grade 0.80 G.T. (4 ft. of 0.20% eU3O8). This cut-off is estimated using a long-term uranium price of US$40 per pound U3O8. (4) Numbers may not add due to rounding. The EFN resource estimate was audited by RPA and accepted as a current Mineral Resource estimate for Energy Fuels under NI 43-101. Present Condition of the Property and Work Completed to Date The following section has been prepared by the Company and is not based exclusively on the Henry Mountains Technical Report. The Tony M Property was developed from 1977 to 1983 with a double entry system including two parallel declines spaced 50 ft. apart. The declines measure 9 feet by 12 feet in cross- section, have crosscuts on 50-foot centers, have a minus 3% grade, serve as the primary fresh air intake, and are 10,200 feet in length. By January 31, 1983, over 18 miles of underground workings had been developed at the 91 Tony M Property. The underground workings were allowed to flood after mining activities were suspended in 1984. The southern one- half of the underground workings remained dry, as they are located above the static water table. The underground workings were planned as a random room and pillar approach with pillar extraction by a retreat system. Mining equipment consisted of slushers and rubber-tired, five- to ten-ton capacity load-haul-dump units. Exhaust ventilation was provided by five bored ventilation shafts, six feet in diameter, each with a 75-HP exhaust fan mounted at the shaft collar. By early 2007, work on reactivating the Tony M Property was carried out by Denison, and surface and underground rehabilitation and repairs were conducted. Surface facilities to support mining activities were constructed, including administration and maintenance facilities, site power and communications, and an evaporation pond for evaporation of water from the underground workings. Worker housing was established in the town of Ticaboo, Utah. As rehabilitation work advanced, ventilation was re-established. The water level in the underground workings rose to historic pre-mining activity levels, and upon reaching the flooded workings, dewatering activities were also initiated. During the rehabilitation work, limited amounts of “cleanup mineralized material” were removed. As areas of the underground workings were made ready for mining activities, extraction of mineralized materials increased steadily. Dewatering continued at an average rate of 125 gallons per minute during these activities. Denison placed the Tony M Property on temporary closure status at the end of November 2008, and dewatering activities have ceased. The project is being maintained in a state ready to resume operations as market conditions warrant. All of the Company housing and property in Ticaboo has been sold by Energy Fuels. There is no existing infrastructure on the Bullfrog Property. The Henry Mountains Complex was acquired by the Company in June 2012, through the acquisition of the US Mining Division from Denison. The cost of the Henry Mountains Complex has been fully impaired, and as of December 31, 2017, the total cost attributable to the Henry Mountains Complex and its associated equipment on the financial statements of the Company was nil. The Company’s Planned Work The Company intends to continue its evaluation activities at the Bullfrog Property during 2018. The Company is also conducting care and maintenance activities on the Tony M Property, in order to maintain it on standby, pending improvements in uranium prices. The planned drilling in the permitting stage will be postponed until the uranium price improves sufficiently. 92 The La Sal Project Unless stated otherwise concerning land tenure and permitting efforts, the following technical and scientific description of the La Sal Project is derived from a technical report titled "Technical Report on La Sal District Project (Including the Pandora, Beaver, and Energy Queen Projects), San Juan County, Utah, U.S.A.", dated March 25, 2014, prepared by Douglas C. Peters, CPG, of Peters Geosciences, in accordance with NI 43-101 (the “La Sal Technical Report”). The La Sal Technical Report includes an updated NI 43-101 compliant Mineral Resource estimate. The author of the La Sal Technical Report is a “qualified person” and “independent” of the Company within the meaning of NI 43-101. A copy of the La Sal Technical Report is available on SEDAR at www.sedar.com and on EDGAR at www.sec.gov. The La Sal Project does not have known reserves, and is therefore considered under SEC Industry Guide 7 definitions to be exploratory in nature, despite uranium extraction activities occurring as recently as 2012. Project Description & Location The La Sal Project is an underground project that consists of four mineral properties within close proximity of one another, including (from east-to-west) the Pandora (Snowball) Property, the Beaver (La Sal) Property, the Redd Block Property, and the Energy Queen Property. The La Sal Project is located in San Juan County, Utah near the town of La Sal. Other properties within the La Sal Project (but not described in the La Sal Technical Report) include the Pine Ridge property, east of the Pandora property, and unpatented mining claims west of the Energy Queen Property. The La Sal trend, which includes the La Sal Project, has a long history of uranium and vanadium production. Deposits from this district have been successfully milled at several historic mills in the region including Union Carbide’s (Umetco's) mill at Uravan, Colorado, the Climax Uranium mill in Grand Junction, Colorado, the Atlas mill at Moab, Utah and Energy Fuels’ White Mesa Mill near Blanding, Utah. 93 Operations at the La Sal Project are currently on standby. The extraction of all resources at the La Sal Project has been by conventional underground methods for over 40 years and, once mining activity resumes, will continue by such methods. These methods have been used very successfully in the region for over 70 years. The nature of the Salt Wash uranium-vanadium deposits require a random room and pillar mining configuration. The deposits are accessed from the surface via declines depending on the depth to mineralization and geologically suitable sites for portals, as is the case for the La Sal and Pandora/Snowball Properties. Deposits may also be accessed through vertical shafts, such as the shafts located at the Beaver and Energy Queen Properties. The Salt Wash uranium deposits are usually thinner than the underground height needed for personnel and equipment access. Therefore, the mineralized material is often extracted by employing a split-shooting method, which serves to separate mineralized material and waste as it is broken. Accessibility, Climate, Local Resources, Infrastructure and Physiography The La Sal Project is easily accessed from the all-weather Utah State Highway 46. Utah 46 enters the project land near the southwest corner of ML-49313 (Section 36, T28S, R24E) about three miles east of the intersection of Utah 46 with U.S. Highway 191 at La Sal Junction. Utah 46 stays within or very near the project land for the next 9 miles to the east. All State and U.S. highways in this area are paved roads. The area is semi-arid. Temperatures range between an average low of 41°F to an average high of 72°F. Less than ten inches of precipitation falls per year. Winters are not severe, although there are numerous snow storms, the temperature drops below 0°F at times, and snow can accumulate to over a foot in the lower areas and more than two feet at times on Pine Ridge. The region of the La Sal Project central area is characterized by a broad shallow valley of hay fields and pasture lands at an elevation between 6,400 and 7,000 feet. Hills cut by small canyons occur at the west end and even higher elevations of about 7,800 feet are reached at Pine Ridge on the east end. All elevations within four miles of the center and west end of the property support moderate growths of sage and rabbitbrush along with 94 other brush, forbs, cactus, yucca, and grasses. Higher elevations contain juniper and piñon pine in the rocky soils along with scrub oak, aspen, and ponderosa pine on Pine Ridge to the east. La Sal, Utah is a small town, currently home to about 200 people. It has been a hub to area ranchers, uranium and copper miners, and oil and gas workers for many years. Larger population centers of Moab and Monticello, Utah are 22 miles north and 34 miles south, respectively, from La Sal Junction on Highway 191. Before the cessation of mining activities at the Beaver and Pandora Properties in late 2012, many of the workers also came from the Nucla-Naturita and the Dove Creek areas of Colorado, each about 55 miles away to the east and south, respectively. Larger cities with industrial supply houses include Cortez, Colorado about 100 miles to the south and Grand Junction, Colorado about 140 miles to the north. Electric transmission and distribution lines exist throughout the project area, of sufficient size to supply the load the projects demanded in the past. Several substations exist, and the electricity supply is adequate for additional demand. Natural gas is also available for any future production needs. Ownership The La Sal Project is held by Energy Fuels’ subsidiary, EFR Colorado Plateau LLC under private surface use and access leases, private mineral leases, Utah State Mineral Leases, San Juan County surface use, access, and mineral leases, and, after the Company reduced the property position by dropping claims without affecting the Mineral Resource, 210 unpatented mining claims on land managed by the BLM or USFS, that are either owned by Energy Fuels (81 claims) or leased by Energy Fuels (129 claims). After the claim drop, the total land package now consists of approximately 9,080 acres. The unpatented claims cover about 3,350 acres, the seven Utah State leases total approximately 2,220 acres, the San Juan County leased land contains just over 263 acres, and the six separate surface access and nine private parcel mineral leases apply to a total of 3,170 acres. The property covers all, or parts of the following Sections: Sections 31, 32, and 33, T28S, R25E; Sections 4, 5, 6, and 7, T29S, R25E; Sections 25, 26, 31, 32, 33, 34, 35, and 36, T28S, R24E; Sections 1, 2, 3, 4, 5, 6, 7, 11, and 12, T29S, R24E; Section 36, T28S, R23E; and Sections 1, and 12, T29S, R23E, SLBM, San Juan County, Utah. Annual holding costs consist of rental fees to the BLM at $155 per year per claim, due on or before September 1st each year. An affidavit of the payment to the BLM must be filed with the appropriate County each year for a nominal fee of about $10 per claim. This applies to all unpatented claims whether owned or leased by Energy Fuels. Annual holding costs for State leases and private leases vary, ranging between $500 and $13,500 for State Leases and $480 and $20,340 for private leases. The Company is also required to pay production royalties at varying rates for unpatented mining claims and private leases. The Utah State production royalties are fixed at 8% on uranium and 4% on vanadium. The Company generally has entered into surface access agreements sufficient to allow access for its mining activities. Permitting Mineral extraction facilities on private and public lands in Utah require an approved Notice of Intent (“NOI”) with the Utah Division of Oil, Gas and Mining (“UDOGM”). If the facility generates water, a ground water discharge permit is required for the treatment plant and ponds, and a surface water discharge permit is required for discharge of treated water. Both permits are issued through the State of Utah Division of Water Quality ("DWQ"). Air permits for air emissions including radon are issued by the Utah Division of Air Quality (“DAQ”); however, smaller mines are typically exempt. Water well permits, water rights, and stream alteration permits are also issued through the DWQ. On federal land, all the state permits listed above are required, as well as a Plan of Operations approved through a NEPA review by the responsible federal land managing agency. The Company’s mineral facilities at the La Sal Project are all existing facilities in historic mining areas, and approvals by the BLM and USFS have been obtained under EAs and Findings of No Significant Impact (“FONSIs”) under NEPA. The Energy Queen and Redd Block IV Properties are located on private land and were permitted with UDOGM in the early 1980s by Union Carbide. The Energy Queen Property was developed and has conducted mineral extraction, but the Redd Block IV Property was discontinued soon after the start of construction. A mine and reclamation plan amendment for the Energy Queen Property was approved by the UDOGM on September 22, 2009. This amendment allows the Company to install water treatment and other new surface facilities to support extraction of up to 250 tons per day (“tpd”) of mineralized materials. Water discharge permits to allow initial and ongoing discharge of water from underground workings were also approved by the DWQ in 2009. Energy Fuels initiated permitting plans for additional facility expansion in 2012, but then deferred these plans when the Redd Block IV resource was acquired in the Denison acquisition. Engineering studies are being conducted to determine if the Redd Block IV resource can be extracted from the Energy Queen shaft and surface facilities. If this proves to be the case, the Energy Queen UDOGM permit would be updated to include the Redd Block IV area as well as other resources that have been acquired since the 2009 amendment. A Small Source Exemption that is in place for air emissions would also need to be replaced with an air permit because of the increased surface disturbance. 95 Though currently in standby status, existing mining operations at the Pandora, Beaver, La Sal and Snowball Properties are fully permitted with the State of Utah, the BLM, and the USFS. In order to allow expansion of the existing mines, Energy Fuels is in the process of obtaining regulatory approvals for expansion of the Pandora, Beaver, and La Sal operations through the UDOGM, the BLM, and the USFS. In late 2014, an EA, draft Decision Notice and FONSI were issued for public comment. In March 2015, in response to an objection filed by an environmental interest group, the USFS ruled that additional analysis was required before a modified Plan of Operations and EA could be approved for the proposed expansion. An expanded EA was finalized by the USFS and BLM in September 2017 and forwarded to Washington DC offices of the BLM for approval. On February 23, 2018, the BLM and USFS issued the EA, Decision Record (BLM)/Decision Notice (USFS), and FONSI approving the expansion, conditional upon the Company incorporating certain specific requirements into the Plan of Operations amendment and having the required reclamation bond in place. All other regulatory approvals needed for project expansion, including an air emissions permit, are in place. Geologic Setting The Colorado Plateau covers nearly 130,000 square miles in the Four Corners region of the U.S. The La Sal Project and other properties held by Energy Fuels lie in the Canyon Lands Section in the central and east-central part of the Colorado Plateau in Utah and Colorado. The Colorado Plateau’s basement rocks are mostly Proterozoic metamorphics and igneous intrusions. The area was relatively stable throughout much of the Paleozoic and Mesozoic Eras with minor uplifts, subsidences, and tiltings resulting in fairly flat-lying sedimentary rocks ranging from evaporites, limestones, and marine clastic sediments, through eolian sandstones, to detritus of fluvial systems. The significant uranium deposits in the La Sal Project occur in the late Jurassic Morrison Formation. The Morrison comprises two members in the La Sal area. The lower member, the Salt Wash, is the main uranium host. The upper part of the Morrison is the Brushy Basin Member; it is from 350 to 450 feet thick. The Salt Wash, approximately 300 feet thick, consists of about equal amounts of fluvial sandstones and mudstones deposited by meandering river systems flowing generally toward the east. The Brushy Basin was deposited mostly on a large mud flat, probably with many lakes and streams. Much of the material deposited to form the Brushy Basin originated from volcanic activity to the west. The majority of the recovered uranium has come from the upper sandstones of the Salt Wash Member known as the Top Rim (historically referred to as the “ore-bearing sandstone” or OBSS), which ranges from about 60 feet to 100 feet thick. Light-brown and gray sandstones and conglomerates of the 200-foot thick Cretaceous Burro Canyon Formation overlie the Brushy Basin. These crop out in the eastern part of the La Sal Project (over the Pine Ridge, Pandora, and La Sal/Snowball properties). This formation contains interbedded green and purplish mudstones with a few thin limestone beds. The Burro Canyon Formation is exposed covering the Brushy Basin at the west end of the La Sal Project, on the State sections and claims west of the Energy Queen. Locally, silicification altered the limestones to chert and some of the sandstones to orthoquartzite. Orthoquartzite cobbles and boulders litter the Brushy Basin slopes. In the central part of the La Sal Project (Beaver, Redd Block, and Energy Queen), the Burro Canyon is covered by a layer of alluvium and gravels shed from the La Sal Mountains to the north. These gravels vary in thickness from a thin veneer to over 120 feet thick. The La Sal District uranium-vanadium deposits are similar to those elsewhere in the Uravan Mineral Belt. Host rocks within the areas surrounding the La Sal Project consist of oxidized sediments of the Morrison Formation, exhibiting red, hematite-rich clastic rocks. Individual deposits are localized in areas of reduced, gray sandstone and gray or green mudstone. The Morrison sediments accumulated as oxidized detritus in the fluvial environment. However, there were isolated environments where reduced conditions existed, such as oxbow lakes and carbon-rich point bars. During early burial and diagenesis, the through-flowing ground water within the large, saturated pile of Salt Wash and Brushy Basin material remained oxidized, thereby transporting uranium in solution. When the uranium-rich waters encountered the zones of trapped reduced waters, the uranium precipitated. Therefore, deposits vary greatly in thickness, grade, size, and shape. Vanadium may have been leached from iron-titanium mineral grains and subsequently deposited along with, or prior, to the uranium. History Numerous underground mines near outcrops in the eastern part of the La Sal trend (in the La Sal Creek Canyon District) were mined for vanadium during the early 1900s. Sometime after World War II (approximately 1948-1954), exploration work on Morrison Formation outcrops in the west end of the district resulted in the discovery of the Rattlesnake mine (open pit) two miles west-southwest of the Energy Queen shaft. Deeper deposits of the central La Sal trend (in the area of the La Sal Project) were discovered in the 1960s and developed for production in the 1970s through vertical shafts and declines. The La Sal Project and La Sal Creek District production, through 1980, amounted to about 6,426,000 pounds U3O8 (average grade of 0.32% U3O8) and nearly 29,000,000 pounds V2O5 (average grade of 1.46%). Most production in the district was derived from fluvial sandstones, mainly in the upper part of the Salt Wash Member of the Morrison Formation of Jurassic age. 96 The Pandora Property was operated by Atlas Minerals in the 1970s and early 1980s. Umetco Minerals (Union Carbide) operated the Snowball, La Sal, and Beaver properties during the same time period. The Energy Queen property, then known as the Hecla Shaft, was started in 1979 by the Union Carbide/Hecla Joint Venture. The Energy Queen stopped mining activities in 1983 due to inadequate uranium prices. GEUMCO (General Electric Uranium Mining Company) operated the Pine Ridge property in the late 1970s, producing from a sandstone lens in the Brushy Basin Member of the Morrison Formation. Pine Ridge was acquired by Minerals Recovery Corporation in 1981, which developed a decline to the Salt Wash Member of the Morrison Formation, but halted mining activities before any significant extraction of mineralized materials. A small project conducted mining activities in the eastern part of Section 2 (ML-49596) during the early 1980s. The amount of uranium extracted from this project is unknown. Low uranium and vanadium prices forced all mining activities throughout the district to cease about 1991. Mineralized materials from these projects have been successfully processed at the Company’s currently operating White Mesa Mill, and the now dismantled Uravan Mill (Umetco) and Moab Mill (Atlas). Denison (previously named International Uranium Corporation, or “IUC”) began mining activities at the Pandora Property in 2006 and later from the Beaver shaft and La Sal decline. During the 2007 to 2013 time period, 446,000 tons of mineralized material were mined from the La Sal Complex and processed at the White Mesa Mill. This material had an average grade of 0.20% U3O8 and 1.02% V2O5 and contained 1,774,000 pounds of uranium and 9,098,000 pounds of vanadium. From 2008 through mid-2012, Denison drilled 225 exploration and fill-in (confirmation) holes in the project area. Energy Fuels drilled another 27 holes on the Energy Queen Property and the State land to the northwest of the Energy Queen Property from 2007 through 2012. Due to declining uranium prices, mining activities ceased in October 2012 at the Beaver/La Sal Property and in December 2012 at the Pandora Property. Both projects were put on a standby status and are currently maintained in conditions that would allow them to be placed back into production within a few months’ time. The Company owns the data on some 2,200 drill holes within the boundary of the property held as the La Sal Project. Mineralization The uranium- and vanadium-bearing minerals occur as fine-grained coatings on the detrital grains. They fill pore spaces between the sand grains, and they replace some carbonaceous material and detrital quartz and feldspar grains. The primary uranium mineral is uraninite (pitchblende) (UO2) with minor amounts of coffinite (USiO4OH). Montroseite (VOOH) is the primary vanadium mineral, along with vanadium clays and hydromica. Traces of metallic sulfides occur. In outcrops and shallow oxidized areas of older mines in the surrounding areas, the minerals now exposed are the calcium and potassium uranyl vanadates, tyuyamunite, and carnotite. Some stoping areas in the Beaver/La Sal and Pandora/Snowball Properties are well over 1,000 feet long and several hundred feet wide. The Indicated Mineral Resources of the Redd Block and Energy Queen Properties identified through drilling are of similar size. Individual mineralized beds vary in thickness from several inches to over 6 feet. Throughout much of the La Sal district there are three horizons in the Top Rim that host the mineralization. They are 25-40 feet apart. Kovschak and Nylund (1981) report no apparent disequilibrium problems in the other mining episodes of the La Sal area. Mining activities and milling by Denison and Energy Fuels shows that well-calibrated gamma probes equate well to the mill head grades indicating no significant disequilibrium exists. This is generally true of the Salt Wash uranium deposits because of the age of the mineralization and the hydrologic history of the host rocks. Therefore, Energy Fuels has no reason to anticipate any disequilibrium conditions within the unmined portions of the deposits on the project property. Mineral Resources Estimates Since the La Sal Project covers a length of ten miles and includes several project sites and facilities, the La Sal Project was divided into four blocks: Pandora, Beaver/La Sal, Redd Block and Energy Queen. The mineral resource estimation for the La Sal Project is based on the gamma logs from 1,993 historic rotary drill and core holes, 247 holes drilled by Energy Fuels and Denison from 2007 to 2012, and approximately 500 underground long holes. Mineral Resource estimates have been calculated using a modified polygonal method. The mineralization in the La Sal Project is interpreted as being hosted in the Top Rim sandstone of the Salt Wash Member of the Morison Formation. Total thickness of the host sandstone is between 60 and 100 feet. 97 La Sal Mineral Resources – Uranium and Vanadium(1)(2)(3)(4)(5) Classification Zone Energy Queen Redd Block Beaver/La Sal La Sal Measured Resources (M) Pandora Energy Queen Redd Block Beaver/La Sal La Sal Indicated Resources (I) Pandora Tons (000) Grade % eU3O8 Pounds eU3O8 (000) Grade % V2O5 Pounds V2O5 (000) 262 336 215 196 81 35 9 7 0.19% 0.19% 0.19% 0.18% 0.17% 0.07% 0.18% 0.14% 971 0.97% 1,260 0.98% 800 701 268 47 33 19 0.98% 0.94% 0.87% 0.35% 0.96% 0.73% 5,100 6,615 4,199 3,682 1,409 249 173 99 Total (M & I) 1,142 0.18% 4,100 0.94% 21,525 Energy Queen Redd Block Beaver/La Sal La Sal Inferred Resources Pandora Total Inferred Resources Notes: 43 95 29 18 0.09% 0.09% 0.11% 0.12% 79 0.48% 171 0.47% 67 44 0.60% 0.66% 417 900 352 232 185 0.10% 362 0.51% 1,902 (1) The Mineral Resource estimate in this table complies with the requirements of NI 43-101, and the classifications comply with CIM definition standards and do not represent reserves under SEC Industry Guide 7. Mineral resources that are not reserves do not have demonstrated economic viability. See “Cautionary Note to U.S. Investors Concerning Disclosure of Mineral Resources,” above. (2) Mineral Resources are estimated at a uranium grade x thickness (G.T.) cut-off of 0.20 G.T. (2 ft. of 0.10% eU3O8). (3) Mineral Resources are estimated using a long-term uranium price of US$65 per pound U3O8 and a vanadium price of US $6.50 per pound V2O5. (4) The average V2O5:U3O8 ratio used for estimating the vanadium Mineral Resources is 5.25:1. This value was based on historical milling of the mineralized material at White Mesa Mill. (5) Numbers may not add due to rounding. Present Condition of the Property and Work Completed to Date Permanent structures existing at the Energy Queen Property include the head frame and a metal building containing an office, shop, showers, warehouse, and the hoist. The compressor is located in a separate building. One cased vertical ventilation hole was established into the underground working level. A small water treatment building and settling ponds are located on the San Juan County land in Section 5. In the past, water was treated with barium chloride to remove radium. The Beaver and La Sal Properties are accessed through the La Sal decline with rubber-tired equipment. The principal shop, offices, and warehouse facilities used by all properties in the district are housed at the surface facilities of the La Sal decline. There are large fenced yards, as well as buildings for equipment and supply storage. It is used as a central receiving site for bulk and large orders, which are then distributed to the other Energy Fuels’ properties in the district and other parts of the region. The shop areas include facilities specific to electrical equipment, drills, mobile diesel equipment, and welding. Engineering, geology, safety, environmental, and supervisory and clerk offices are located here. There are also staff and underground crew’s dry rooms. Ample stockpile space is available for easy truck load-out for transporting mineralized material to the White Mesa Mill. Electrical lines and substations exist and are adequately sized for any future extraction potential of the Mineral Resources. The Beaver and La Sal Properties are dry, so no water treatment facilities are needed. 98 The surface infrastructure at the Beaver shaft location consists of the hoist house, hoist, and head frame. The shaft is 690 feet deep to the underground haulage level at the loading pockets top grizzlies, and 750 feet total depth. There are three pockets, two of 70-ton capacity and one of 90-ton capacity. This arrangement allows for separation of mineralized material and waste. The skips dump into a bin from which the mineralized material is trucked a short distance to a stockpile and subsequently loaded in to the trucks for haulage to the White Mesa Mill. The shaft conveyance system is certified for man trips, although the routine access for personnel is through the La Sal decline. Another building houses the compressors, which supply compressed air for the underground workings in the Beaver Project. Power lines and substations are in place. The Beaver Property is dry underground; therefore, no water treatment facilities exist. Access into the Pandora Property is through a decline with rubber-tired equipment. Surface facilities here are less than at the other projects. They consist of a small office and shop buildings. A third building is used for storage of materials and equipment. Power lines exist to the property with enough capacity for the required load of potential future mining activities. The Pandora Property is dry underground. In 1980, Umetco was planning to sink another shaft to access the Redd Block Mineral Resources. The project did not progress far. The infrastructure at the Redd Block Property associated with a possible new shaft consists of a cleared and leveled site large enough for future construction of all surface facilities that would be required. The power line and transformers are installed, and the concrete base for a compressor building has been poured. As mining activities progress, a water table in the Salt Wash sandstone host horizon will be between the current Beaver Property western underground workings advance and the east end of the Redd Block Mineral Resources. Seven monitor wells were installed by Denison around this proposed shaft site. Five surety bonds, totaling $1,186,700 have been posted with regulatory authorities to secure reclamation at the various project facilities. The Company acquired the Energy Queen Property in December 2006. The remainder of the La Sal Project, was acquired by the Company in June 2012, through the acquisition of the Denison US Mining Division. The cost of the La Sal Project has been fully impaired, and as of December 31, 2017, the total cost attributable to the La Sal Project and its associated equipment on the financial statements of the Company was nil. The Company’s Planned Work The Company intends to continue its permitting and related activities at the La Sal Project during 2018, as described under the heading "Permitting," above. The Company is also conducting care and maintenance activities on the facilities at the various properties within the La Sal Project, in order to maintain them on standby, pending improvements in uranium prices. Energy Fuels has evaluated numerous targets for additional surface drilling at the La Sal Project. However, there are no plans to perform the drilling in 2018. During 2018, the Company plans to rehabilitate the La Sal mine access decline, which has deteriorated during the last 5 years of standby status. 99 The Daneros Project Unless otherwise stated concerning land tenure and permitting efforts, the following scientific and technical description of the Daneros Project is derived from a technical report titled “Updated Report on The Daneros Mine Project, San Juan County, Utah, U.S.A.,” dated March 2, 2018, prepared by Douglas C. Peters, Certified Professional Geologist, of Peters Geosciences, Golden, Colorado in accordance with NI 43-101 (the “Daneros Mine Technical Report”). The author of the Daneros Mine Technical Report is a “qualified person” and is “independent” of the Company within the meaning of NI 43-101. The Daneros Mine Technical Report is available on SEDAR at www.sedar.com and on EDGAR at www.sec.gov. The Daneros Project does not have known reserves, and is therefore considered under SEC Industry Guide 7 definitions to be exploratory in nature, despite uranium extraction occurring as recently as 2012. Project Description and Location The Daneros Project is an underground project located in the Red Canyon portion of the White Canyon District in San Juan County, Utah, approximately 65 miles west of the White Mesa Mill. The Company holds a 100% interest in various groups of mining claims, including Daneros and adjoining historical sites, which can be developed in conjunction with the Daneros Project. The previous owner of the Daneros Project, Utah Energy Corporation (“UEC”), gathered the necessary environmental data and obtained the approvals to open an underground uranium project in May 2009. UEC commenced active mining activities, including constructing a decline into the main Daneros deposit. The first loads of mineralized material from the Daneros Project were delivered to the White Mesa Mill in December 2009, and a toll milling campaign was conducted in the second half of 2010. The Daneros Project was acquired by the Company in June 2012 along with all of Denison’s U.S. Mining Division. Prior to being placed on standby in October 2012, mineralized material from the Daneros Project was delivered to the White Mesa Mill and processed for Energy Fuels’ account. 100 The extraction of all resources in the Daneros Project is by conventional underground methods. These methods have been used successfully in the region for over 70 years. The nature of the Shinarump uranium deposits requires a random room and pillar mining configuration. The deposits have irregular shapes and occur within several close-spaced, flat or slight-dipping horizons. Uranium mineralization often rolls between horizons. The use of rubber-tired equipment allows the workers to follow the mineralized material easily in the slight dips and to ramp up or down to the other horizons. The deposit is accessed from the surface through a 450 feet decline at a gradient of -15%. The Shinarump deposits are usually thinner than the underground height needed for personnel and equipment access. Therefore, the mineralized material is extracted by a split-shooting method. The project also employs an underground long-hole exploration drilling program, reaching out as much as 400 feet ahead of and adjacent to the workings, as guided by the project geologist. Accessibility, Climate, Local Resources, Infrastructure and Physiography The Daneros Project is located 3.3 miles southwest of Fry Canyon, Utah and is accessed via Radium King Road, which is maintained by San Juan County, approximately 13 miles south of Utah Highway 95. A series of bulldozed tracks and drill roads provide access throughout the project area, but access to the mesa tops is very limited. Electric power is generated on site. The shipping distance from the Daneros Project to the White Mesa Mill is about 65 miles. The semi-arid climate of the White Canyon area is characterized by large daily and yearly temperature ranges and total annual precipitation of approximately 10 to 16 inches, mostly as sporadic, intense summer thunderstorms typical of the Colorado Plateau region. Winter snowfall is moderate and rarely stays on the ground very long. Weather conditions pose no impediment to year round work on the project. Apart from previous mining activities, the only commercial land use purposes are cattle grazing and tourism activities such as hiking and mountain biking. Due to a shortage of water and thin soils, much of the White Canyon area is unsuitable for agriculture. 101 The project area is remotely located relative to water and power infrastructure. Housing for workers is mostly in camp trailers in Fry Canyon, or they commute from Blanding, Utah 65-miles to the east or farther. Blanding is a town large enough to host regional industrial activities, including stores and supply houses of sufficient size and inventory to meet most of the needs of an operation the size of the Daneros Project. The project area is located along a north-south trending canyon, which is a tributary to Red Canyon, also known as Bullseye Canyon. The Red Canyon drainage flows westerly for approximately 25 miles to the Colorado River where it joins Lake Powell at the head of Good Hope Bay. The project portal area comprises steeply sloping, rocky ground and scree along the eastern slope of Bullseye Canyon. Very steep to vertical, and at times overhanging, cliffs 400 feet high rise from the slope about 250 feet above the portal. Vegetation in the project area consists of sagebrush, juniper and piñon in the hills and slopes, while desert grasses, forbs, and shrubs are evident within the valley floors and on the mesa tops. Elevations in the region range from about 5,300 feet at the Fry Canyon townsite to over 7,000 feet on the surrounding mesa tops. The project portal is at about 5,750 feet above sea level. Ownership The Daneros Project is owned by the Company’s subsidiary EFR White Canyon Corp. The property consists of 141 unpatented mining claims located on federal land administered by the BLM in San Juan County, Utah, plus the State lease totaling approximately 3,072 acres. The property lies in Sections 1, (11, and 12 were dropped in 2014) T37S, R15E, SLM, Sections (4 dropped in 2014), 5, 6, 7, 8, (10, 11, 15, 17 dropped in 2014), and 18, T37S, R16E (and Section 31 and 33, T36S, R16E dropped in 2014). The mining claims are maintained by making annual payments of US $155 per claim per year to BLM due September 1st each year, along with a nominal filing fee paid to the county within 30 days of the BLM filing of about $10 per claim. Work expenditures are not required. Holders of unpatented mining claims are generally granted surface access to conduct mineral exploration and mining activities. However, additional mine permits and plans are generally required prior to conducting exploration or mining activities on such claims. A number of the claims bear production royalties. Claims hosting the Daneros deposit are subject to royalties ranging between 15% of "market value" of the mineralized material and 2.5% of gross proceeds as described in further detail in the Daneros Mine Technical report. Other claims are owned by the Company without encumbrances. The State lease carries the standard Utah royalty of 8% on uranium and 4% on vanadium. Sufficient surface rights are in place for contemplated mining activities and waste storage. Since no milling activities are contemplated on the Daneros Project, no areas are required for tailings storage, heap leach pads, or processing plant sites. Permitting The primary permits required for mining activities at the Daneros Project include a mine permit issued by UDOGM and a Plan of Operations ("PO") approved by the BLM under the NEPA review process. UEC submitted a Plan of Operations for the Daneros Mine in 2008 that proposed a seven-year life of mine with production of up to 100,000 tons of mineralized material within a 4.5 acre disturbed area footprint. In 2012, the BLM issued an EA based on the 2008 PO that was subject to public review and comment. Following approval of the PO, an appeal was filed by Uranium Watch and associated environmental interest groups. The appeal was denied by the Utah BLM State office, then appealed to the Department of Interior Board of Land Appeals ("IBLA"), and denied by IBLA in September of 2012. In early 2013, an amended PO and a Large Mine NOI were submitted to the BLM and UDOGM, respectively. The modified PO would allow production of up to 500,000 tons of mineralized material over a 20-year period and an expansion of the disturbed area footprint to 46 acres. An EA was issued for public comment in July 2016 and finalized by the BLM in late 2016. With the designation of the Bears Ears National Monument ("BENM") in December 2016, the BLM essentially suspended review while they considered if expanded mining operations, now adjacent to the monument, might adversely affect the monument. In September 2017 an updated EA that determined there would be no new impacts to the monument was forwarded to BLM Washington for approval. Since then, the BENM boundaries were modified by Presidential Executive Order, and the Daneros mine would be at least 15 miles from the nearest boundary. The EA, FONSI and PO amendment were issued by BLM on February 23, 2018. The Company expects approval of the NOI amendment later in 2018. Daneros was initially permitted by the UDOGM under a Small Mine Permit approved in 2009. The Notice of Intent ("NOI") for a Large Mining permit was submitted to UDOGM in early 2013. In 2015 UDOGM concluded its technical and administrative reviews of the application. Approval of the NOI has been pending BLM approval of the EAand Decision Notice, which were issued on February 23, 2018, subject to certain specified requirements. As a result, the Company expects UDOGM approval of the modified PO and Large Mine permit within three to six months from the date of this Form 10-K. 102 Geological Setting Major uranium deposits of the east-central Colorado Plateau district occur principally in two fluvial sandstone sequences. The older is located at or near the base of the Upper Triassic Chinle Formation and the other occurs in the Late Jurassic Salt Wash Member of the Morrison Formation. The main uranium-bearing unit at the Daneros Project and throughout the White Canyon district is the fluvial Shinarump Member, a basal, sandstone-conglomerate sequence deposited in a complex stream system, which unconformably overlies and locally scours into oxidized sedimentary units of the Moenkopi Formation. The Shinarump Member consists of predominantly trough-crossbedded, coarse-grained sandstone and minor gray, carbonaceous mudstone and is interpreted as a valley-fill sequence overlain by deposits of a braided stream system. Uranium mineralization appears to be related to low-energy depositional environments in that uranium is localized in fluvial sandstones that lie beneath organic-rich lacustrine-marsh mudstones and carbonaceous delta-front sediments. The reducing environment preserved in these facies played an important role in the localization of uranium. Uranium deposits consist of closely-spaced, lenticular mineralized pods which are generally concordant with bedding in paleochannel sediments. Single mineralized pods range from a few feet to a few hundred feet in length and from less than one to more than 10 feet in thickness. Deposits range in size from a few tons to more than 600,000 tons. The Shinarump deposits generally have low vanadium content, and are therefore not processed for vanadium recovery. The uranium deposit at the Daneros Project, like nearly all others in the White Canyon district, is in the lower part of the Shinarump, especially where it has scoured into the Moenkopi. The lithology, facies, sedimentary structures, and locations within the channel deposits all were important in controlling the migration of fluids and localization of the deposits. Coarser-grained rock is more favorable than fine-grained sand or silt units. Most of the uranium mineralization is overlying impermeable siltstones of the Moenkopi or local siltstone lenses internal of the Shinarump. The lateral edges of channels where they are bounded by mudstones are also favorable locations for mineralization. Historical production from the White Canyon District exceeds 11 million pounds of U3O8. History The White Canyon mining district has a long history of exploration and mining. From 1949-1987 production from the district was 2,259,822 tons at an average grade of 0.24% U3O8 for a total of 11,069,032 pounds placing it second, behind Lisbon Valley, for uranium production from the Chinle Formation on the Colorado Plateau. Exploration for uranium has been going on in the White Canyon area since the late 1940’s. Prospectors used Geiger counters to investigate outcrops of the Shinarump Sandstone. The history of exploration is closely tied to the Atomic Energy Commission (“AEC”) buying program, opening and closing of the several processing facilities in the region, and the fluctuation of the price of uranium. The properties in the Daneros Project area remained idle until 1946. From 1948 until 1951, White Canyon and the nearby Red Canyon and Deer Flat areas were subject to intense exploration. The AEC ore procurement program ended on December 31, 1970, and during the early 1970’s minimal production was recorded from the district. Production from the district increased again by 1974 when the demand for uranium increased due to nuclear power generation. Exploration and production once again increased in the White Canyon District. In 1974, Utah Power and Light Company (“UP&L”) began to acquire properties in the White Canyon district, which included a 100% interest in the Spook-Bullseye property and a 60% interest in the Lark-Royal property both located near the Daneros Project in Red Canyon. Between 1975 and 1985, UP&L conducted several phases of drilling leading to definition of the Lark, Royal, and Bullseye deposits near the modern day Daneros Project. UP&L drilled 595 diamond drill holes with an average depth of 510 feet and, following industry standard procedures, logged all holes using down-hole geophysical (gamma) probes to identify radioactive horizons. Anomalous horizons were sampled and analyzed for uranium. UP&L never started mining activities in the White Canyon district, due to the collapse of the uranium price by 1982. By 1987 the last mines in the White Canyon district closed due to declining economics, socio-political factors and competition from lower cost producers. Following 1987, the properties were idle and little or no exploration activity took place in the White Canyon district. In 1993 UP&L dropped its mining claims in the White Canyon District. In October 1993, Eugene and Merwin Shumway staked the Daneros claims that covered the deposits UP&L had discovered. Eugene and Merwin Shumway quitclaimed their claims to Wilene and Mike Shumway, Terry Leach, and James Lammert in March, 1994. No exploration or development took place between 1994 and 2005. From 2005 to 2007, these individuals began acquiring properties with known historic mineral deposits in the White Canyon district. In 2007, Utah Commodities Pty, Ltd. who later changed its name to White Canyon Uranium Limited (“WCUL”), which operated in the United States through its wholly owned subsidiary, UEC, acquired a 100% interest in the Daneros claims from those individuals. 103 In December 2008, WCUL purchased 33 additional claims, known as the Lark-Royal Project, an extension of the Daneros Project, from Uranium One. WCUL began drilling programs in Bullseye Canyon during 2007. The first program drilled 8 holes within the five Daneros claims. A second program in 2008 drilled 16 diamond drill holes and 1 rotary drill hole. Finally, a third program, also in 2008, drilled 11 diamond drill holes and 9 rotary drill holes. The success of this drilling provided the basis for mineral resource estimates relied upon by WCUL to commence mining activities at the Daneros Project. The Daneros Project was constructed and uranium bearing material was extracted by WCUL, through its subsidiary UEC. WCUL gathered the necessary environmental data and submitted applications for approvals to open an underground facility at Daneros. A PO was submitted to the BLM and was approved in May, 2009, following which UEC commenced active construction at the project, including driving a decline into the main deposit at Daneros. The first loads of mineralized material from the Daneros Project were delivered to the White Mesa Mill in December, 2009, then operated by Denison Mines. In January 2010, Denison entered into a toll milling agreement with UEC, which was then a wholly-owned subsidiary of WCUL. In 2011, Denison acquired all of the issued and outstanding shares of WCUL, including all of the shares of UEC. In June 2012, Energy Fuels acquired all of the issued and outstanding shares of WCUL as part of its acquisition of the U.S. Mining Division from Denison, which included the Daneros Project and all of the shares of UEC (which is now named EFR White Canyon Corp.). Denison, and then the Company, kept the project in operation using the same contractors (until placing it on standby in October 2012 after the Daneros Project Technical Report was written). During the 2009 to 2013 time period, 121,000 tons of mineralized material were mined at the Daneros Mine and processed at the White Mesa Mill. This material had an average grade of 0.26% U3O8 and contained 629,000 pounds of uranium. Mineralization Uraninite (pitchblende) is by far the dominant primary uranium mineral in the Shinarump deposits. It occurs as distinct grains, fine- grained coatings on and pore-fillings between detrital quartz grains, partial replacement of feldspar grains, and as replacement in carbonized wood and other remains of organic matter. Metallic sulfide minerals are often abundant. Where secondary oxidation has occurred, minor amounts of uranyl carbonates, sulfates, and phosphates are found. The source of the uranium is not well established. Overlying shaley units of the Chinle contain clays derived from volcanic ash that is uraniferous. The source area of the arkosic sediments was also a uranium-rich province. Daneros Mineral Resources – Uranium(1)(2)(3)(4)(5) Classification Daneros Measured Resources (M) Daneros Indicated Resources (I) Daneros Total (M & I) Daneros Inferred Resources Notes: Tons (000) Grade % eU3O8 Pounds eU3O8 (000) --- 20 20 7 --- 0.36% 0.36% 0.37% --- 142 142 52 (1) The Mineral Resource estimate in this table complies with the requirements of NI 43-101, and the classifications comply with CIM definition standards and do not represent reserves under SEC Industry Guide 7. Mineral resources that are not reserves do not have demonstrated economic viability. See “Cautionary Note to U.S. Investors Concerning Disclosure of Mineral Resources,” above. (2) Mineral Resources are estimated at a uranium cut-off grade of 0.23% eU3O8. (3) Mineral Resources are estimated using a long-term uranium price of US$55 per pound. (4) Numbers may not add due to rounding. (5) This Mineral Resource accounts for all material mined through October 2012, when Daneros was placed on Standby. Additional Historical Resources The Daneros property contains three historical mines, which produced in the early days of mining in the White Canyon District. These mines are the Lark/Bullseye, the Royal and the Spook. An historical resource estimate for the Lark mine was completed by UP&L in 1974. UP&L estimated that the Lark mine contained approximately 45,000 tons at a grade of 0.30% U3O8 for 265,000 pounds of uranium. This historical resource estimate is based on both surface and underground long-hole drilling. Areas of influence are defined by connecting surface holes that are less than 100 ft. apart and to the mineralized extent of a long hole. 104 Peters Geosciences and the Company do not consider this historical resource estimate to be current mineral resources or reserves as defined under NI 43-101. Energy Fuels has only reviewed a limited number of data in connection with this historical estimate. Readers should be cautioned that a qualified person has not done sufficient work to classify this historical estimate as a current estimate of mineral resources or mineral reserves in accordance with NI 43-101. This historical resource estimate was classified as "Indicated Resources." However, this category was applied without using applicable mining standards and economics, and should not be considered reserves by industry definition. The Company believes this historical estimate is relevant and reliable, as the methodology was well documented and utilized industry standard practice. However, the methodologies used do not reflect current best industry practices. The Company does not consider these historical estimates to be equivalent to current mineral resources or mineral reserves as defined in NI 43-101, nor has the Company completed sufficient work to confirm a NI 43-101 compliant resource. Therefore, the historical estimates cannot, and should not, be relied upon as NI 43-101 resources or reserves. Present Condition of Property and Work Completed to Date The Daneros Project is fully permitted and constructed. The facilities consist of a modular trailer for the project office, two reinforced portals for access to and from the underground workings, a generator building, and an equipment storage and maintenance building. The deposit is accessed from the surface through a 450 foot long decline at a gradient of -15%. Two ventilation shafts daylight on the topographic bench above the underground workings. The Daneros Project was acquired by the Company in June 2012, through the acquisition of the Denison US Mining Division. The cost of the Daneros Project has been fully impaired, and as of December 31, 2017, the total cost attributable to the Daneros Project and its associated equipment on the financial statements of the Company was nil. The Company’s Planned Work We are maintaining the project on care and maintenance. Additional permitting is ongoing as described above. Energy Fuels has reviewed the remaining resources and has evaluated prospective areas for future exploration drilling. There are no plans to perform any drilling in 2018. 105 Non-Material Mineral Properties This section describes certain non-material mineral properties held by the Company. As these projects are not considered material to the Company's business, the Company may choose to pursue or to take under consideration the potential sale, joint venture, trade or other transaction involving one or more of these projects. We hold the following non-material mineral properties: Other ISR Projects The Company's Properties located in the Powder River Basin, Wyoming, are as follows: Our properties in the Powder River Basin of Wyoming, but outside of the Nichols Ranch Project, include 12,480 acres owned 100% by the Company through its wholly owned subsidiary, Uranerz. These properties include: the North Rolling Pin Property, the Reno Creek Property, the West North Butte Property, and the Collins Draw, Willow Creek, East Nichols, North Nichols, Verna Ann, and Niles Ranch properties. The Company, through Uranerz, also holds an 81% interest in the Arkose Joint Venture, which holds an additional 42,952 acres in the Powder River Basin. In general, these ISR projects are located in basins containing sandstones of Tertiary age with known uranium mineralization. Limited exploration was conducted by Uranerz on each project except for Verna Ann and Niles Ranch. The Reno Creek Property consists of three unpatented lode mining claims, 18 mineral leases, and three surface use agreements. The project area covers approximately 1,332.57 acres. The fee land in the project is covered by mineral leases, some of which have annual payments and some of which are paid up leases. The mineral leases have primary terms of 10 years and can be held by production (as defined in the leases). Some of the mineral leases will expire in 2018 and 2019; however the leases generally enable the Company to 106 extend the term of such leases, which the Company has done or intends to do. The fee surface is covered by three Surface Use Agreements, which include damage payments paid on an annual basis. Sixteen of the mining leases have a two-tier royalty based on the price of U3O8 at the time of sale, which is 6% for a U3O8 price less than $45.00 per pound or 8% for a U3O8 price equal to or greater than $45.00 per pound. Two of these leases have a flat 8% of the total gross proceeds. Access to the project is off of Highway 387, which runs through the northern end of the project area. A technical report titled “Technical Report, Reno Creek Property, Campbell County, Wyoming, U.S.A.” dated October 13, 2010, was prepared by Douglass Graves, P.E. of Trec, Inc., in accordance with NI 43-101 (the “Reno Creek Technical Report”). Mr. Graves is a “qualified person” and “independent” of the Company within the meaning of NI 43-101. The Reno Creek Technical Report is available on SEDAR at www.sedar.com. The Reno Creek Technical Report reports the following mineral resources calculated in accordance with NI 43-101. None of these resources are reserves within the meaning of SEC Industry Guide 7. In November 2017, the Company announced that it had entered into an agreement to sell the Reno Creek Property to Uranium Energy Corp. (see 2017 Corporate Developments, above). Reno Creek Mineral Resources - Uranium(1)(2)(3)(4) Classification Reno Creek Measured Resources (M) Reno Creek Indicated Resources (I) Reno Creek Total (M & I) Reno Creek Inferred Resources Tons (000) Grade % eU3O8 Pounds eU3O8 (000) 2,281 0.061% 1,550 0.049% 3,831 0.056% 190 0.037% 2,782 1,511 4,293 142 Notes: (1) The Mineral Resource estimate in this table complies with the requirements of NI 43-101 and the classifications comply with CIM definition standards and do not represent reserves under SEC Industry Guide 7. Mineral resources that are not reserves do not have demonstrated economic viability. See “Cautionary Note to U.S. Investors Concerning Disclosure of Mineral Resources,” above. (2) Mineral Resources are estimated at a uranium grade x thickness (G.T.) cut-off of 0.20 G.T. (minimum grade of 0.03% eU3O8 or minimum thickness of 1 foot). (3) Mineral Resources are estimated using a long-term uranium price of US$65 per pound U3O8. (4) Numbers may not add due to rounding. Wholly-owned Powder River Basin ISR Mineral Resources Through its wholly owned subsidiary, Uranerz, the Company owns properties in the Powder River Basin of Wyoming, but outside of the Nichols Ranch Project, comprising a total of 19,801 acres. These properties include: the North Rolling Pin Property, the West North Butte Property, and the Collins Draw, Willow Creek, East Nichols, North Nichols, Verna Ann, and Niles Ranch properties. The North Rolling Pin property is discussed in the “Technical Report West North Butte Satellite Properties Campbell County, Wyoming, U.S.A.”, dated December 9, 2008, prepared by Douglas H. Graves of TREC, Inc. and Don R. Woody of Woody Enterprises and is available on SEDAR at www.sedar.com. Mr. Graves and Mr. Woody are “qualified persons” and are “independent” of the Company within the meaning of NI 43-101. The West North Butte satellite properties include West North Butte, East North Butte, and Willow Creek, and are described in the Technical Report titled “Technical Report North Rolling Pin Property Campbell County, Wyoming, U.S.A.” dated June 4, 2010, prepared by Douglas H. Graves of TREC, Inc. and is available on SEDAR at www.sedar.com. Mr. Graves is a “qualified person” and is “independent” of the Company within the meaning of NI 43-101. Except as noted, the following description of these properties is based on the foregoing technical reports. 107 Wholly-owned Powder River Basin ISR Mineral Resources(1)(2)(3)(4) Classification Powder River Basin Measured Resources (M) Powder River Basin Indicated Resources (I) Total (M & I) Property Tons (000) Grade % eU3O8 Pounds eU3O8 (000) North Rolling Pin North Rolling Pin West North Butte 310 272 926 0.062 % 0.051 % 0.153 % 1,508 0.116% North Rolling Pin 39 0.042 % 387 278 2,837 3,502 33 2,682 2,714 Powder River Basin Inferred Resources West North Butte 1,117 0.120 % Total Inferred Resources Notes: 1,156 0.117% (1) The Mineral Resource estimate in this table complies with the requirements of NI 43-101, and the classifications comply with CIM definition standards and do not represent reserves under SEC Industry Guide 7. Mineral resources that are not reserves do not have demonstrated economic viability. See “Cautionary Note to U.S. Investors Concerning Disclosure of Mineral Resources,” above. (2) Mineral Resources are estimated at a uranium grade x thickness (G.T.) of 0.20 G.T. (3) Mineral Resources are estimated using a long-term uranium price of US$65 per pound U3O8. (4) Numbers may not add due to rounding. Arkose Joint Venture, Powder River Basin, Wyoming: The Company, through its wholly owned subsidiary Uranerz, holds an undivided 81% interest in the Arkose Joint Venture, which holds an additional 46,748 acres in the Powder River Basin. Uranerz completed the acquisition of its interest in the Arkose Joint Venture mineral properties on January 15, 2008. This acquisition was completed pursuant to a purchase and sale agreement previously announced on September 19, 2007 between Uranerz, and NAMMCO, Steven C. Kirkwood, Robert W. Kirkwood and Stephen L. Payne (collectively, the “NAMMCO Sellers”). In connection with the acquisition of its interest in the Arkose Joint Venture, Uranerz entered into a venture agreement dated as of January 15, 2008 (the “Venture Agreement”) with United Nuclear, LLC (“United Nuclear”), a limited liability company wholly owned by the NAMMCO Sellers and their designee under the purchase and sale agreement. Under the Venture Agreement, United Nuclear will hold (and contribute to) its nineteen percent (19%) working interest in the Arkose Joint Venture, and Uranerz will operate and be the manager of the Venture. Uranerz and United Nuclear agreed to contribute funds to programs and budgets approved under the Arkose Mining Venture in accordance with their respective interests in the Venture. The Arkose Mining Venture includes the following property units on which Uranerz has conducted exploration: South Doughstick • North Jane * • • Cedar Canyon • East Buck South Collins Draw • • Sand Rock • Little Butte • Beecher Draw • Monument Stage • *Now included in the Nichols Ranch Project as part of the Jane Dough Property. Except as noted, the following description of the Arkose Joint Venture properties is based on a technical report titled “Arkose Uranium Project Mineral Resource and Exploration Target, 43-101 Technical Report” dated February 28, 2015, prepared by Douglas L. Beahm, P.E., P.G. of BRS Inc. in accordance with NI 43-101 (the “Arkose Technical Report”). Mr. Beahm is a “qualified person” and is 108 “independent” of the Company within the meaning of NI 43-101. The Arkose Technical Report is available on SEDAR at www.sedar.com. In September of 2016 the Arkose Joint Venture elected to forfeit 190 unpatented lode mining claims covering 3,925 acres from its Kermit property and 144 claims covering 2,975 acres from its Lone Bull property, which constitute all of the Arkose claims in those projects. In addition, four mineral leases comprising 592 acres in the East Buck project were allowed to expire in 2016 without attempting to negotiate extensions to those leases. In 2017, several mineral leases in the Monument, Cedar Canyon, Sand Rock, East Buck and House Creek projects were allowed to expire; however, the Company does not expect the expiry of those property interests to materially affect our ability to continue exploration and extraction activities on our properties. The Arkose Joint Venture properties are comprised of unpatented lode mining claims, state leases and fee (private) mineral leases, summarized as follows as of December 31, 2017: Property Composition Unpatented Lode Mining Claims State Leases Fee (private) Mineral Leases TOTAL Notes: (1) Subject to royalties. Ownership Interest(1) Number of Claims/Leases Acreage (Approximate) 81% 81% 81% 1,338 3 54 1,395 26,523 2,080 10,498 39,101 Arkose JV-owned Powder River Basin ISR Mineral Resources Classification Property Tons (000) Grade % eU3O8 Pounds eU3O8 (000) Energy Fuels Pounds eU3O8 (000)(5) Arkose JV Measured Resources (M) Arkose JV Indicated Resources (I) --- --- Total (M & I) East Buck Little Butte Sand Rock Arkose JV Inferred Resources South Doughstick Total Inferred Resources Notes: --- --- --- --- --- --- 656 0.110% 1,021 0.090% 184 197 0.100% 0.130% --- --- --- 1.436 1.752 381 497 2,058 0.099% 4,066 --- --- --- 1,163 1,419 309 402 3,293 (1) The Mineral Resource estimate in this table complies with the requirements of NI 43-101, and the classifications comply with CIM definition standards and do not represent reserves under SEC Industry Guide 7. Mineral resources that are not reserves do not have demonstrated economic viability. See “Cautionary Note to U.S. Investors Concerning Disclosure of Mineral Resources,” above. (2) Mineral Resources for the Arkose JV are estimated at a uranium grade x thickness (G.T.) cut-off of 0.20 G.T. (minimum grade of 0.02% eU3O8). (3) Mineral Resources are estimated using a long-term uranium price of US$65 per pound. (4) Numbers may not add due to rounding. (5) “Energy Fuels Pounds” represent the 81% Company share of the Arkose Mining Venture properties. 109 Arizona Strip Other Conventional Projects The Pinenut Project is currently in reclamation. Mineral extraction at our Arizona 1 Project commenced in December 2009, and continued until the project was placed on standby in February 2014 due to the depletion of the readily available resources. The Wate Project and EZ Project are in the evaluation stage. Permitting at the Wate Project and the EZ Project is currently on hold. A description of the Wate Project can be found in the NI 43-101 report titled “NI 43-101 Technical Report on Resources Wate Uranium Breccia Pipe- Northern Arizona, USA” dated March 10, 2015, prepared by Allan Moran and Frank A. Daviess of SRK Consulting (U.S.) Inc. and available on www.sedar.com and on EDGAR at www.sec.gov. The EZ Project is described in the technical report titled “Technical Report on the EZ1 and EZ2 Breccia Pipes, Arizona Strip District, U.S.A.” dated June 27, 2012, prepared by David A. Ross and Christopher Moreton of Roscoe Postle Associates and available on www.sedar.com and on EDGAR at www.sec.gov. Other Arizona Strip Properties Mineral Resources – Uranium(1)(4)(5) Classification Arizona Strip Measured Resources (M) Arizona Strip Indicated Resources (I) Total (M & I) Arizona Strip Inferred Resources Total Inferred Resources Property --- --- Wate(2) EZ1 and EZ2(3) Tons (000) Grade % eU3O8 Pounds eU3O8 (000) --- --- --- 71 224 295 --- --- --- 0.79 % 0.47 % 0.55% --- --- --- 1,118 2,105 3,223 110 Notes: (1) The Mineral Resource estimate in this table complies with the requirements of NI 43-101, and the classifications comply with CIM definition standards and do not represent reserves under SEC Industry Guide 7. Mineral resources that are not reserves do not have demonstrated economic viability. See “Cautionary Note to U.S. Investors Concerning Disclosure of Mineral Resources,” above. (2) Mineral Resources for Wate are estimated at a uranium cut-off grade of 0.15% eU3O8 and for EZ1 and EZ2 are estimated at a uranium cut-off grade of 0.20% eU3O8. (3) Mineral Resources for Wate are estimated using a long-term uranium price of US$38 per pound U3O8, and for EZ1 and EZ2 are estimated using a long-term uranium price of US$53 per pound U3O8. (4) The Mineral Resources do not include any remaining resources for Arizona 1, because those given in the “Technical Report on the Arizona Strip Uranium Project, Arizona, U.S.A.” dated June 27, 2012 do not adequately address changes to the resource as a result of mining and the addition of potential additional mineralization as a result of underground drilling associated with mining activities. (5) Numbers may not add due to rounding. Colorado Plateau As a result of declining uranium prices, the Rim property (the “Rim Property”) was placed on standby in March 2009, by the previous operator, Denison. It is maintained so that it can be restarted with little relative effort or development costs. The Rim Property is located 15 miles northeast of Monticello, Utah in San Juan County. The property consists of 26 unpatented lode mining claims, a private lease, and a Utah State Mineral Lease totaling about 1,100 acres. No exploration is planned for 2018. The Whirlwind Project comprises 126 unpatented lode mining claims covered by three Mineral Leases and a Utah State Mineral Lease of 320 acres for a total acreage of about 2,800 acres. The property size (as reported in the NI 43-101 report “Updated Technical Report on Energy Fuels Resources Corporation’s Whirlwind Property (Including Whirlwind, Far West, and Crosswind Claim Groups and Utah Metalliferous Minerals Lease ML-49312) Mesa County, Colorado and Grand County, Utah,” dated March 15, 2011, prepared by Douglas C. Peters of Peters Geosciences, and available on www.sedar.com) has been reduced since the acquisition. The retained property continues to cover the known mineralized areas that are described in the Technical Report. The Whirlwind Project straddles the Utah/Colorado state line 4.5 miles southwest of Gateway, Colorado. The Whirlwind Project was refurbished by the Company in 2008, and remains on standby status. Exploration drill projects were conducted in 2007, 2008, 2009, 2010, 2011 and 2012. No exploration is planned for 2018. The Sage Plain Project is a uranium/vanadium property in the evaluation stage. It is located in southeast Utah about 15 miles northeast of Monticello, Utah in the southwest continuation of the Uravan Mineral Belt. The project area includes one historic property, the Calliham Mine, which was operated by Atlas Minerals in the 1980s and briefly by Umetco Minerals Corp. in the early 1990’s. Calliham 111 ceased production due to low uranium prices. It consists of two fee mineral leases covering about 960 acres (Calliham and Crain) and a Utah State lease of 640 acres. A third fee mineral lease (Skidmore) has been terminated since the preparation of the Technical Report "Updated Technical Report on Sage Plain Project (Including the Calliham Mine) San Juan County, Utah, U.S.A." dated March 18, 2015, prepared by Douglas C. Peters of Peters Geosciences. No exploration is planned for 2018. Other Colorado Plateau Properties Mineral Resources – Uranium and Vanadium(1)(5) Classification Colorado Plateau Measured Resources (M) Colorado Plateau Indicated Resources (I) Total (M & I) Colorado Plateau Inferred Resources Total Inferred Resources Notes: Property Sage Plain(2)(4) Sage Plain(2)(4) Whirlwind(3) Sage Plain(2)(4) Whirlwind(3) Tons (000) Grade % eU3O8 Pounds eU3O8 (000) Grade % V2O5 Pounds V2O5 (000) 240 13 188 441 10 437 447 0.16 % 0.10 % 772 1.32 % 6,350 26 0.77 % 199 0.29 % 1,095 0.96 % 3,598 0.21% 1,894 1.15% 10,147 0.13 % 25 0.94 % 0.23 % 2,000 0.74 % 0.23% 2,025 0.74% 188 6,472 6,660 (1) The Mineral Resource estimate in this table complies with the requirements of NI 43-101, and the classifications comply with CIM definition standards and do not represent reserves under SEC Industry Guide 7. Mineral resources that are not reserves do not have demonstrated economic viability. See “Cautionary Note to U.S. Investors Concerning Disclosure of Mineral Resources,” above. (2) Mineral Resources for Sage Plain are estimated at a uranium cut-off grade of 0.10% eU3O8. This cut-off grade is based on using a long-term uranium price of US$63 per pound U3O8 and a vanadium price of US$6.75 per pound V2O5.Where vanadium assay data is available, that information is used to estimate the vanadium Mineral Resource. Where assay data is not available an average V2O5:U3O8 ratio of 8.6:1 is used to estimate the vanadium Mineral Resource. (3) Mineral Resources for Whirlwind are estimated at a uranium cut-off grade of 0.06% eU3O8. This cut-off grade is based on using a long-term uranium price of US$77.50 per pound U3O8 and a vanadium price of US$7.50 per pound V2O5. Vanadium grades are based on assays where taken, and otherwise estimated at the average V2O5:U3O8 ratio of 3.24:1. (4) The Mineral Resources given for Sage Plain differ from those given in the “Updated Technical Report on Sage Plain Project (Including the Calliham Mine), San Juan County, Utah, U.S.A.” dated March 18, 2015. The Skidmore Lease portion of the property was dropped in 2016 and that Mineral Resource has been subtracted from that shown in the table. (5) Numbers may not add due to rounding. Department of Energy (DOE) Lease Tracts Exploration Properties We currently hold eight DOE uranium leases in the Uravan Mineral Belt portion of Mesa, Montrose, and San Miguel Counties, Colorado. The tracts are designated C-SR-12, C-SR-16A, C-AM-19, C-AM-20, C-CM-24, C-G-26, and C-G-27. A Federal Court Order in 2011 halted all physical work on these tracts until the DOE completes a full EIS on its Uranium Leasing Program. The Final EIS was made available and the Record of Decision was published in the Federal Register on May 12, 2014. The DOE’s preferred alternative is to resume the leasing program essentially as it was before the law suit. However, the DOE has not yet petitioned the Court to remove the stay on the leases; therefore, we have no plans for any additional exploration work in 2018. Prior to the 2011 stay, we conducted drilling on CM-24 and G-26. The HC Claims (Calamity Mesa) and Torbyn Claims (Tenderfoot Mesa) were dropped by the Company during 2017. Neither property contained NI 43-101 compliant Mineral Resources. Dropped Properties 112 ITEM 3. LEGAL PROCEEDINGS Other than routine litigation incidental to our business, or as described below, the Company is not currently a party to any material pending legal proceedings that management believes would be likely to have a material adverse effect on our financial position, results of operations or cash flows. White Mesa Mill In November 2012, the Company was served with a Plaintiff’s Original Petition and Jury Demand in the District Court of Harris County, Texas, claiming unspecified damages from the disease and injuries resulting from mesothelioma from exposure to asbestos, which the Plaintiff claims was contributed to by being exposed to asbestos products and dust while working at the White Mesa Mill. The Company does not consider this claim to have any merit, and therefore does not believe it will materially affect our financial position, results of operations or cash flows. In January, 2013, the Company filed a Special Appearance challenging jurisdiction and certain other procedural matters relating to this claim. This action was dismissed on February 21, 2018 and the matter is now finished. In January, 2013, the Ute Mountain Ute tribe filed a Petition to Intervene and Request for Agency Action challenging the Corrective Action Plan approved by the State of Utah Department of Environmental Quality (“UDEQ”) relating to nitrate contamination in the shallow aquifer at the White Mesa Mill site. This challenge is currently being evaluated, and may involve the appointment of an administrative law judge to hear the matter. The Company does not consider this action to have any merit. If the petition is successful, the likely outcome would be a requirement to modify or replace the existing Corrective Action Plan. At this time, the Company does not believe any such modification or replacement would materially affect our financial position, results of operations or cash flows. However, the scope and costs of remediation under a revised or replacement Corrective Action Plan have not yet been determined and could be significant. In April 2014, the Grand Canyon Trust filed a citizen suit in federal District Court for alleged violations of the Clean Air Act at the White Mesa Mill. In October 2014, the plaintiffs were granted leave by the Court to add further purported violations to their April 2014 suit. The Complaint, as amended, alleged that radon from one of the Mill’s tailings impoundments exceeded the standard; that the mill is in violation of a requirement that only two tailings impoundments may be in operation at any one time; and that certain other violations related to the manner of measuring and reporting radon results from one of the tailings impoundments occurred in 2013. The Complaint asked the Court to impose injunctive relief, civil penalties of up to $37,500 per day per violation, costs of litigation including attorneys’ fees, and other relief. The Company believes the issues raised in the Complaint are being addressed through the proper regulatory channels and that we are currently in compliance with all applicable regulatory requirements relating to those matters. Cross motions for summary judgment were heard by the District Court on November 17, 2016. On September 15, 2017, the Court issued its order in favor of the Company on all counts and dismissing the plaintiffs motions. This decision was not appealed by the plaintiffs, and the matter is now finished. Canyon Project In March, 2013, the Center for Biological Diversity, the Grand Canyon Trust, the Sierra Club and the Havasupai Tribe (the “Canyon Plaintiffs”) filed a complaint in the U.S. District Court for the District of Arizona (the “District Court”) against the Forest Supervisor for the Kaibab National Forest and the USFS seeking an order (a) declaring that the USFS failed to comply with environmental, mining, public land, and historic preservation laws in relation to our Canyon Project, (b) setting aside any approvals regarding exploration and mining operations at the Canyon Project, and (c) directing operations to cease at the Canyon Project and enjoining the USFS from allowing any further exploration or mining-related activities at the Canyon Project until the USFS fully complies with all applicable laws. In April 2013, the Plaintiffs filed a Motion for Preliminary Injunction, which was denied by the District Court in September, 2013. On April 7, 2015, the District Court issued its final ruling on the merits in favor of the Defendants and the Company and against the Canyon Plaintiffs on all counts. The Canyon Plaintiffs appealed the District Court’s ruling on the merits to the Ninth Circuit Court of Appeals, and filed motions for an injunction pending appeal with the District Court. Those motions for an injunction pending appeal were denied by the District Court on May 26, 2015. Thereafter, Plaintiffs filed urgent motions for an injunction pending appeal with the Ninth Circuit Court of Appeals, which were denied on June 30, 2015. The hearing on the merits at the Court of Appeals was held on December 15, 2016. On December 12, 2017, the Ninth Circuit Court of Appeals issued its ruling on the merits in favor of the Defendants and the Company and against the Canyon Plaintiffs on all counts. The Canyon Plaintiffs have petitioned the Ninth Circuit Court of Appeals for a rehearing en banc. On February 21, 2018, the Court of Appeals ordered the Defendants and the Company to file a response to the Canyon Plaintiffs' petition for a rehearing en banc. If a rehearing is granted and the Canyon Plaintiffs are successful on their appeal on the merits, the Company may be required to maintain the Canyon Project on standby pending resolution of the matter. Such a required prolonged stoppage of shaft sinking and mining activities could have a significant impact on our future operations. 113 The mine safety disclosures required by section 1503(a) of the Dodd-Frank Wall Street Reform and Consumer Protection Act and Item 104 of Regulation S-K are included in Exhibit 95.1 of this Annual Report. ITEM 4. MINE SAFETY DISCLOSURE 114 PART II ITEM 5. MARKET FOR THE REGISTRANT’S COMMON EQUITY, RELATED STOCKHOLDER MATTERS AND ISSUER PURCHASES OF EQUITY SECURITIES Market Information Energy Fuels’ Common Shares are listed and traded on the NYSE American under the symbol “UUUU” and on the TSX under the symbol “EFR.” The following table sets forth, for the calendar quarters indicated, the high and low sales price per common share of Energy Fuels, in each case as reported on the NYSE American and the TSX. In addition, the table sets forth the quarterly cash dividends per share declared by Energy Fuels with respect to its Common Shares. Energy Fuels NYSE American (US Dollars) Energy Fuels TSX (Canadian Dollars) High Lo w Declared High Lo w Declared Dividends Dividends $ $ $ $ $ $ $ $ 2.66 $ 2.25 $ 1.85 $ 2.03 $ 2.96 $ 2.70 $ 2.56 $ 2.37 $ 1.73 $ 1.48 $ 1.58 $ 1.30 $ 1.96 $ 2.10 $ 1.51 $ 1.30 $ — $ — $ — $ — $ — $ — $ — $ — $ 3.47 $ 3.00 $ 2.33 $ 2.64 $ 4.04 $ 3.46 $ 3.28 $ 2.40 $ 2.32 $ 1.98 $ 1.99 $ 1.66 $ 2.83 $ 2.73 $ 2.01 $ 1.76 $ — — — — — — — — 2017 First Quarter Second Quarter Third Quarter Fourth Quarter 2016 First Quarter Second Quarter Third Quarter Fourth Quarter As of March 8, 2018, the closing bid quotation for our Common Shares was $1.58 per share as quoted by the NYSE American. As of March 8, 2018, Energy Fuels had 75,739,978 Common Shares issued and outstanding, held by approximately 50,000 shareholders. Most shares are registered through intermediaries, making the precise number of shareholders difficult to obtain. Dividend Policy We have never declared cash dividends on our common shares. We anticipate that we will retain any earnings to support operations and to finance the growth of our business. Therefore, we do not expect to pay cash dividends in the foreseeable future. Any further determination to pay cash dividends will be at the discretion of our Board of Directors and will be dependent on the financial condition, operating results, capital requirements, and other factors that our Board of Directors deems relevant. Recent Sales of Unregistered Securities None. Use of Proceeds None. Repurchase of Securities During 2017, neither we nor any of our affiliates repurchased any of our Common Shares registered under Section 12 of the Exchange Act. 115 Equity Compensation Plan Information The following table provides information as of December 31, 2017, concerning stock options and restricted stock units (“RSU’s”) outstanding pursuant to our 2015 Omnibus Equity Incentive Compensation Plan (the “Equity Incentive Plan”), which has been approved by the Company’s shareholders. Energy Fuels does not have an equity compensation plan that has not been approved by shareholders. The table also includes options that we assumed as part of the Uranerz acquisition. Number of Common Shares to be issued upon exercise of outstanding options, warrants and rights 3,159,945 Weighted-average exercise price of outstanding options, warrants and rights (USD) $3.63 Number of Common Shares remaining available for future issuance 4,276,738 778,379 3,938,324 $5.84 $5.80 Nil 4,276,738 Plan Category Energy Fuels Omnibus Equity Incentive Compensation Plan (1) (2) Uranerz Replacement Options Total (1)(2) Notes: (1) Includes 1,250,468 stock options and 1,909,477 restricted stock units. Each restricted stock unit vests as to 50% one year after the date of grant, as to another 25% two years after the date of grant and as to the remaining 25% three years after the date of grant. Upon vesting, each restricted stock unit entitles the holder to receive one common share without any additional payment. (2) 1,909,477 restricted stock units have been excluded from the weighted average exercise price because there is no exercise price. Energy Fuels Equity Incentive Plan The Equity Incentive Plan was approved by the board of directors on January 28, 2015 and by shareholders on June 18, 2015. The Equity Incentive Plan supersedes and replaces the Energy Fuels Stock Option Plan, which was the Company’s prior equity incentive program. All stock options previously granted pursuant to the Energy Fuels Stock Option Plan which remain outstanding are incorporated into the Equity Incentive Plan. Employees, directors, and consultants of the Company and its affiliates are eligible to participate in the Equity Incentive Plan. The Board of Directors, or a Committee authorized by the Board of Directors (the “Committee”), administers the Equity Incentive Plan. The Committee may grant awards for non-qualified stock options, incentive stock options, stock appreciation rights, restricted stock, deferred share units, restricted stock units, performance shares, performance units, and stock-based awards to eligible participants. The ability to grant a broad range of equity incentive awards is consistent with the practices of similar public companies. Pursuant to the rules of the TSX, the Equity Incentive Plan must be renewed by approval of Energy Fuels shareholders every three years. Uranerz Options On June 18, 2015, in connection with the acquisition of Uranerz, Energy Fuels issued 2,048,000 stock options of Energy Fuels, by assuming the then-existing options granted pursuant to the Uranerz 2005 Stock Option Plan, as amended on June 10, 2009 (the “2005 Stock Option Plan”). These options are now exercisable for Common Shares, subject to the exchange ratio set out in the Merger Agreement that governed the acquisition of Uranerz. No further stock options will be granted pursuant to the 2005 Stock Option Plan. The options have varying expiry dates with the last options expiring in June 2025. Stock Performance Graph The performance graph below shows Energy Fuels’ cumulative total 5-year return based on an initial investment of $100 in Energy Fuels common shares beginning on December 31, 2012, as compared with the Russell 2000 Index, NYSE American Natural Resources Index, NYSE Composite, NASDAQ Composite, and a peer group consisting of Ur-Energy, Peninsula Energy, Berkeley Energia, Toro Energy, Uranium Energy Corp., Paladin Energy, UEX Corp., Denison Mines Corp., URI, and Energy Resources of Australia. The chart shows yearly performance marks over a five year period. This performance chart assumes: (1) $100 was invested on December 31, 2012 in Energy Fuels common shares along with the Russell 2000 Index, NYSE American Natural Resources Index, NYSE Composite, NASDAQ Composite, and the peer group’s common stock; and (2) all dividends are reinvested. Dates on the chart represent the last trading day of the indicated fiscal year. 116 Exchange Controls There are no governmental laws, decrees or regulations in Canada that restrict the export or import of capital, including foreign exchange controls, or that affect the remittance of dividends, interest or other payments to nonresident holders of the securities of Energy Fuels, other than Canadian withholding tax. See “Certain Canadian Federal Income Tax Considerations for U.S. Residents” below. Certain Canadian Federal Income Tax Considerations The following is, as of the date hereof, a summary of the principal Canadian federal income tax considerations generally applicable under the Income Tax Act (Canada) and the regulations promulgated thereunder (the "Tax Act") to a holder who acquires, as beneficial owner, our Common Shares, and who, for purposes of the Tax Act and at all relevant times: (i) holds the Common Shares as capital property; (ii) deals at arm’s length with, and is not affiliated with, us; (iii) is not, and is not deemed to be resident in Canada; and (iv) does not use or hold and will not be deemed to use or hold, our Common Shares in a business carried on in Canada, or a Non-Resident Holder. Generally, our Common Shares will be considered to be capital property to a Non-Resident Holder provided the Non-Resident Holder does not hold our Common Shares in the course of carrying on a business of trading or dealing in securities and has not acquired them in one or more transactions considered to be an adventure or concern in the nature of trade. Special rules, which are not discussed in this summary, may apply to a Non-Resident Holder that is an insurer that carries on an insurance business in Canada and elsewhere. Such Non-Resident Holders should seek advice from their own tax advisors. This summary is based upon the provisions of the Tax Act in force as of the date hereof, all specific proposals, or the Proposed Amendments, to amend the Tax Act that have been publicly and officially announced by or on behalf of the Minister of Finance (Canada) prior to the date hereof and management’s understanding of the current administrative policies and practices of the Canada Revenue Agency (the "CRA") published in writing by it prior to the date hereof. This summary assumes the Proposed Amendments will be enacted in the form proposed. However, no assurance can be given that the Proposed Amendments will be enacted in their current form, or at all. This summary is not exhaustive of all possible Canadian federal income tax considerations and, except for the Proposed Amendments, does not take into account or anticipate any changes in the law or any changes in the CRA’s administrative policies or practices, whether by legislative, governmental, or judicial action or decision, nor does it take into account or anticipate any other federal or any provincial, territorial or foreign tax considerations, which may differ significantly from those discussed herein. Non-Resident Holders should consult their own tax advisors with respect to an investment in our Common Shares. This summary is of a general nature only and is not intended to be, nor should it be construed to be, legal or tax advice to any prospective purchaser or holder of our Common Shares, and no representations with respect to the income tax consequences 117 to any prospective purchaser or holder are made. Consequently, prospective purchasers or holders of our Common Shares should consult their own tax advisors with respect to their particular circumstances. Currency Conversion Generally, for purposes of the Tax Act, all amounts relating to the acquisition, holding, or disposition of our Common Shares must be converted into Canadian dollars based on the exchange rates as determined in accordance with the Tax Act. The amounts subject to withholding tax and any capital gains or capital losses realized by a Non-Resident Holder may be affected by fluctuations in the Canadian-U.S. dollar exchange rate. Disposition of Common Shares A Non-Resident Holder will not generally be subject to tax under the Tax Act on a disposition of a common share, unless the common share constitutes “taxable Canadian property” (as defined in the Tax Act) of the Non-Resident Holder at the time of disposition and the Non-Resident Holder is not entitled to relief under an applicable income tax treaty or convention. Provided the common shares are listed on a “designated stock exchange”, as defined in the Tax Act (which currently includes the TSX and NYSE American) at the time of disposition, the common shares will generally not constitute taxable Canadian property of a Non-Resident Holder at that time, unless at any time during the 60-month period immediately preceding the disposition the following two conditions are satisfied concurrently: (i) (a) the Non-Resident Holder; (b) persons with whom the Non-Resident Holder did not deal at arm’s length; (c) partnerships in which the Non-Resident Holder or a person described in (b) holds a membership interest directly or indirectly through one or more partnerships; or (d) any combination of the persons and partnerships described in (a) through (c), owned 25% or more of the issued shares of any class or series of our shares; and (ii) more than 50% of the fair market value of our shares was derived directly or indirectly from one or any combination of: real or immovable property situated in Canada, “Canadian resource properties”, “timber resource properties” (each as defined in the Tax Act), and options in respect of, or interests in or for civil law rights in, such properties. Notwithstanding the foregoing, in certain circumstances set out in the Tax Act, the common shares could be deemed to be taxable Canadian property. Even if the common shares are taxable Canadian property to a Non-Resident Holder, such Non-Resident Holder may be exempt from tax under the Tax Act on the disposition of such common shares by virtue of an applicable income tax treaty or convention. A Non-Resident Holder contemplating a disposition of Common Shares that may constitute taxable Canadian property should consult a tax advisor prior to such disposition. Receipt of Dividends Dividends received or deemed to be received by a Non-Resident Holder on our Common Shares will be subject to Canadian withholding tax under the Tax Act. The general rate of withholding tax is 25%, although such rate may be reduced under the provisions of an applicable income tax convention between Canada and the Non-Resident Holder’s country of residence. For example, under the Canada-United States Income Tax Convention (1980) as amended, or the Treaty, the rate is generally reduced to 15% where the Non-Resident Holder is a resident of the United States for the purposes of, and is entitled to the benefits of, the Treaty. ITEM 6. SELECTED FINANCIAL DATA Selected financial data about Energy Fuels for the last five years is set forth in the table below. You should read the data in the table in conjunction with the information contained in Item 7. “Management’s Discussion and Analysis of Financial Condition and Results of Operations” and the consolidated financial statements and related notes set forth in Item 8, “Financial Statements and Supplementary Data.” Total assets ($000s) Total long-term obligations ($000s) $ $ 185,338 $ 48,175 $ 196,457 $ 46,487 $ 192,280 $ 38,937 $ 128,589 $ 21,348 $ 216,781 26,539 2017 2016 At December 31 2015 2014 2013 118 Sales ($000s) Net loss ($000s) Basic and diluted loss per share $ $ Dividends per share Impairment of plant and equipment and mineral properties Impairment of assets held for sale $ $ Impairment losses on goodwill $ For the year ended December 31 2017 2016 2015 2014 2013 31,046 $ (27,990) $ 54,552 $ (39,864) $ 61,351 $ (82,357) $ 46,253 $ (86,635) $ (0.39) $ Nil (0.70) $ Nil (2.46) $ Nil (4.41) $ Nil 64,321 (36,590) (2.27) Nil — $ (3,799) $ — $ — $ — $ — $ (8,224) $ — $ (47,730) $ (80,071) $ — $ — $ — — — Note: Over the five years shown above, the Company completed significant acquisitions of businesses and assets. See Item 1, "Description of Business; Development of the Business - Major Transactions over the Past Five Years" above. 119 ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS The following discussion and analysis should be read in conjunction with our financial statements for the three years ended December 31, 2017 and the related notes thereto. This discussion and analysis contains forward-looking statements that involve risks, uncertainties, and assumptions. Our actual results may differ materially from those anticipated in these forward-looking statements as a result of many factors, including, but not limited to, those set forth under the section heading “Item 1A. Risk Factors” and elsewhere in this Annual Report. See section heading “Cautionary Statement Regarding Forward-Looking Statements.” Outlook Overview Operations and Sales Outlook Overview The Company plans to extract and/or recover uranium from the following sources in 2018 (each of which is more fully described below): • Nichols Ranch Project • Alternate Feed Materials • Pond Return at the White Mesa Mill Our planned operations, together with our existing inventories, are expected to produce finished uranium in excess of our existing sales contracts. In response to continued uranium price weakness and market uncertainty and, until such time that improvement in uranium market conditions is observed or suitable sales contracts can be entered into, the Company expects to defer further wellfield development at its Nichols Ranch Project. In addition, the Company will keep the Alta Mesa Project and its conventional mining properties on standby. The Company is also seeking new sources of revenue, including new sources of alternate feed materials and new fee processing opportunities at the White Mesa Mill that can be processed under existing market conditions, largely unrelated to uranium sales prices, as well as evaluating the possibility of recovering vanadium from existing pond solutions at the White Mesa Mill. In addition, the Company is continuing to manage its activities and assets conservatively and maintaining its substantial uranium resource base and ISR and conventional uranium extraction and recovery capabilities. Shaft sinking at the Canyon Project has been completed and all field activities will be completed by mid-2018, with only engineering, procurement and construction management activities expected to continue through 2018. The Company will continue cost-cutting measures in 2018. The Company will also continue its support of the Trade Petition discussed below, and will evaluate additional acquisition and disposition opportunities that may arise. Extraction and Recovery Activities Overview The Company recovered approximately 1,570,000 pounds of U3O8 during the year ended December 31, 2017, of which 624,000 pounds were for the account of the Company and the remainder were for the accounts of third parties under various alternate feed toll processing and other arrangements. The Company expects to produce 460,000 to 520,000 pounds of U3O8 in the year ending December 31, 2018 for its own account. The Company currently has finished goods inventory and uranium extraction and recovery capabilities that exceed the commitments contained in its existing sales contracts. As a result, both ISR and conventional uranium extraction and/or recovery have been, and are expected to continue to be, maintained at reduced levels until such time as market conditions improve sufficiently. ISR Activities We extracted and recovered approximately 259,000 pounds of U3O8 from Nichols Ranch for the year ended December 31, 2017. The Company expects to produce approximately 140,000 to 160,000 pounds of U3O8 in the year ending December 31, 2018 from Nichols Ranch. At December 31, 2017, the Nichols Ranch wellfields had nine header houses extracting uranium. Until such time that improvement in uranium market conditions is observed or suitable sales contracts can be entered into, the Company intends to defer development of further header houses at its Nichols Ranch Project and to keep the Alta Mesa Project on standby. 120 Permitting of the Jane Dough Property adjacent to the Nichols Ranch Project was completed in 2017, which is well in advance of our need to begin wellfield construction and production at that property. Also, the Hank Project is fully permitted to be constructed as a satellite facility to the Nichols Ranch Plant. Conventional Activities Conventional Extraction and Recovery Activities The White Mesa Mill recovered approximately 1,312,000 pounds of U3O8 during the year ended December 31, 2017, primarily from alternate feed materials and from dissolved uranium in the Mill’s tailings management system not recovered from previous processing activities (“Pond Return”). Of these 1,312,000 pounds of U3O8, 366,000 pounds were for the account of the Company and the remainder were for the accounts of third parties under various alternate feed toll processing and other arrangements. During the year ending December 31, 2018, the Company expects to recover approximately 320,000 to 360,000 pounds of U3O8 at the White Mesa Mill for its own account. All of this uranium is expected to be from alternate feed materials and Pond Return. In addition, during 2018, the Company expects to recover additional uranium for the accounts of third parties under various alternate feed toll processing and other arrangements, returning all finished uranium product from those activities to the generators of the feed materials. The fees from those toll processing and other arrangements are expected to cover the Company's processing costs relating to those activities and to provide the Company with a reasonable margin. The White Mesa Mill has historically operated on a campaign basis, whereby uranium recovery is scheduled as mill feed, cash needs, contract requirements, and/or market conditions may warrant. The Company currently expects that planned processing activities will keep the Mill in operation through the end of 2018. The Company is also actively pursuing opportunities to process new and additional alternate feed sources, low grade ore from third parties in connection with various uranium clean-up requirements, further recovery of Pond Return, and is also evaluating the possibility of recovering vanadium from existing pond solutions. Successful results from these activities would allow the Mill to extend the 2018 campaign into 2019 and beyond. However, in the event we are unable at any time to secure sufficient feed sources to justify full operation of the Mill through 2018 or at any time thereafter, the Company would expect to place uranium recovery activities at the Mill on standby at that time, until sufficient mill feed becomes available. While on standby, the Mill would continue to dry and package material from the Nichols Ranch Plant and continue to receive and stockpile alternate feed materials for future milling campaigns. Each future milling campaign would be subject to receipt of sufficient mill feed and resulting cash flow that would allow the Company to operate the Mill on a profitable basis or that would result in all or a portion of the Mill's standby costs being recovered. Conventional Evaluation, Permitting and Standby Activities The Company has completed shaft sinking at the Canyon Project, along with underground drilling to further evaluate the deposit. On October 10, 2017, the Company filed an NI 43-101 report updating its resource estimate for the Canyon Project. The updated resource estimate significantly increased the pounds of uranium contained in the Canyon Project over previously reported estimates. It also upgraded a large portion of the resources from the inferred category to the measured and indicated categories, and quantified significant copper resources. The Company believes it has identified reasonable options for processing these copper resources at its White Mesa Mill as a by-product with uranium. If successful, the recovered copper would provide a credit that would effectively lower the U3O8 production cost per pound at the mine. During 2018, the Company plans to complete the construction of the main mine sump at the Canyon Project before mid-year 2018, after which time all field activities will have been completed. The Company plans to continue to carry out engineering, procurement and construction management activities in 2018, including additional bench and pilot plant scale metallurgical test work of the uranium/copper mineralization, as well as pursue any additional permitting actions that may be required to recover copper at the White Mesa Mill. The timing of our plans to extract and process mineralized materials from this project will be based on the results of this additional evaluation work, along with market conditions, available financing and sales requirements. The Company is selectively advancing certain permits at its other major conventional uranium projects. The Company plans to continue the licensing and permitting of the Roca Honda Project, a large, high-grade conventional project in New Mexico, with the Record of Decision currently now scheduled to be completed in 2019. The Company will also maintain required permits at the Company’s conventional standby projects including the La Sal Project and the Daneros Project. In January 2017, the Company obtained the necessary permits to mine the open pit and underground resources of its Sheep Mountain Project in Wyoming. The Company will also continue to evaluate the Bullfrog Property at its Henry Mountains Project. Expenditures for certain of these projects have been adjusted to coincide with expected dates of price recoveries based on our forecasts. All of these projects serve as important pipeline assets for the Company’s future conventional production capabilities, as market conditions warrant. A number of the Company’s conventional mines also have substantial vanadium resources which the Company is currently evaluating, particularly with the recent increases in vanadium prices to over $13 per pound. 121 Cost Cutting Measures During 2017, the Company engaged in significant cost-cutting measures. We reduced our total number of employees from 195 in 2016 to an estimated 108 for 2018, representing a reduction of approximately 45% since 2016. Further, since 2016, the Company has streamlined its executive management team, including recently announced management changes, by reducing the number of its senior executive officers from six to three, representing a reduction of 50%, and a significant reduction in general and administrative expenses. The Company has also significantly reduced its land holding costs, while maintaining its core properties and resource base. Since 2014, annual land holding costs have been reduced at our conventional properties by approximately 59% from $1.12 million in 2014 to $0.46 million in 2017, and since 2015 we have reduced expenditures related to our Wyoming ISR properties by approximately 43% from approximately $1.77 million in 2015 to $1.01 million in 2017. Finally, since the beginning of 2016, the Company has sold or entered into agreements to sell surplus equipment and other assets as well as non-core mineral properties for total proceeds to the Company of approximately $6.44 million. The Company will continue to pursue additional cost cutting initiatives, including further reductions in the scope of certain development initiatives, the potential sale or abandonment of certain non-core properties and the sale of excess mining equipment and other assets. Sales During the year ended December 31, 2017, the Company completed sales under its existing contracts of 520,000 pounds of U3O8, including 320,000 pounds under three long-term contracts and 200,000 pounds under a spot contract. Of these deliveries, 120,000 pounds represent the final deliveries under one of these contracts. The Company has four remaining contracts, which require deliveries of 650,000 pounds of U3O8 in 2018. Of the 650,000 pounds of expected sales in 2018, 400,000 pounds are being sold pursuant to two long-term contracts with a fixed price of $61.30 per pound, 50,000 pounds are being sold pursuant to a contract having a fixed price of $24.75 per pound, and 200,000 pounds are being sold at a 0.5% discount to spot prices in effect at the times of delivery. Of the long-term contract deliveries, the 400,000 pounds to be delivered in 2018 represent the final deliveries under all sales contracts. The Company expects to have sufficient existing inventory or uranium recovery to meet all of its commitments to sell these 650,000 pounds of uranium in 2018. The Company is monitoring market conditions for additional sales opportunities, as it currently has no further contracts for the sale of uranium following its 2018 deliveries. Selective additional spot sales may be made in 2018 as necessary to generate cash for operations and development activities. The Company also continues to pursue new sources of revenue, including additional alternate feed materials and other sources of feed for the White Mesa Mill. Trade Petition In January 2018, the Company participated in 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 describes how uranium and nuclear fuel from state-owned and state-subsidized enterprises in Russia, Kazakhstan, Uzbekistan, and China potentially 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 President's Buy American Policy. The remedies, if granted, would be expected to strengthen the U.S. uranium mining industry, bolster national defense, and improve supply diversification for U.S. utilities and their customers. The Company intends to continue its support of this action during 2018. It should be noted, however, that there can be no certainty of the outcome of the petition, and therefore the outcome of this process is uncertain. Results of Operations The following table summarizes the results of operations for the years ended December 31, 2017, 2016 and 2015 (in thousands of dollars): 122 Revenues Uranium concentrates Alternate feed materials processing and other Total revenues Costs and expenses applicable to revenue Costs and expenses applicable to uranium concentrates Costs and expenses applicable to alternate feed materials and other Total costs and expenses applicable to revenue Impairment of inventories Gross Profit Other operating costs and expenses Development, permitting and land holding Standby costs Abandonment of mineral properties Impairment of assets held for sale Accretion of asset retirement obligation Total other operating costs and expenses Selling, general & administration Selling costs Intangible asset amortization General and administration Costs directly attributable to acquisitions Total selling, general & administration Years ended December 31, 2016 2015 2017 $ $ 24,467 6,579 31,046 $ 54,432 120 54,552 14,676 4,729 19,405 3,305 8,336 8,821 3,659 287 3,799 1,733 18,299 275 3,297 14,923 — 18,495 35,315 138 35,453 5,362 13,737 21,118 10,234 1,036 — 906 33,294 379 3,319 15,519 — 19,217 60,696 655 61,351 37,384 233 37,617 — 23,734 8,762 10,765 2,770 — 494 22,791 316 5,364 12,325 6,886 24,891 Operating loss before impairment (28,458) (38,774) (23,948) Impairment of goodwill and property, plant and equipment Impairment of property, plant and equipment and mineral properties Impairment of goodwill Impairment Total Operating Loss Interest expense Other income (expense) Income tax expense Net loss Basic and diluted loss per share Results of Operations — — — (28,458) (2,101) 2,569 — — — — (38,774) (2,289) 1,199 — 8,224 47,730 55,954 (79,902) (2,035) (420) — $ $ (27,990) $ (39,864) $ (82,357) (0.39) $ (0.70) $ (2.46) Year ended December 31, 2017 compared to year ended December 31, 2016 For the year ended December 31, 2017 the Company recorded a net loss of $27.99 million or $0.39 per share compared with a loss of $39.86 million or $0.70 per share for the year ended December 31, 2016. 123 For the year ended December 31, 2017, the Company recorded an operating loss before impairment of $28.46 million compared with an operating loss before impairment of $38.77 million for the year ended December 31, 2016. Revenues The Company’s revenues from uranium are largely based on delivery schedules under long-term contracts, which can vary from quarter to quarter. Revenues for the year ended December 31, 2017 totaled $31.05 million compared with $54.55 million in the year ended December 31, 2016. Revenues for the year ended December 31, 2017 totaled $31.05 million, of which $24.47 million were sales of 520,000 pounds of U3O8, which included the sale of 320,000 pounds of U3O8 pursuant to term contracts at an average price of $62.72 per pound and the sale of 200,000 pounds of U3O8 into contracts based on spot market prices at an average price of $21.99 per pound. Revenues for the year ended December 31, 2016 totaled $54.55 million, of which $54.43 million were sales of 1,147,933 pounds of U3O8, which included the sale of 850,000 pounds of U3O8 pursuant to term contracts at an average price of $56.64 per pound and the sale of 297,933 pounds of U3O8 based on spot market prices at an average price of $21.10 per pound. Operating Expenses Uranium recovered and costs and expenses applicable to revenue In the year ended December 31, 2017, the Company recovered 1,570,000 pounds of U3O8 of which 624,000 pounds were for the Company's own account and 946,000 pounds were for the account of a tolling customer. Of the 624,000 pounds recovered for its own account, 365,000 pounds were from alternate feed sources and 259,000 pounds were from ISR recovery activities. In the year ended December 31, 2016, the Company recovered 1,015,000 pounds of U3O8 for its own account. Of the 1,015,000 pounds recovered, 335,000 pounds were from the Company's ISR recovery activities and 680,000 pounds were from the Company's Conventional recovery activities. The Conventional recovery activities included recovery of 249,000 pounds from alternate feed sources and 431,000 pounds from conventional feed material. Costs and expenses applicable to revenue for the year ended December 31, 2017 totaled $19.41 million, compared with $35.45 million for the year ended December 31, 2016. Included in cost and expenses applicable to revenue is $4.73 million related to toll processing and other (2016 - $0.14 million). The decrease in the cost of sales was primarily attributable to a decrease in the quantity of U3O8 sold year over year as discussed above partially offet by an increase in toll processing and other. Costs of goods sold averaged $28.22 per pound and $30.88 per pound in the years ended December 31, 2017 and 2016, respectively. Other Operating Costs and Expenses Development, permitting and land holding For the year ended December 31, 2017, the Company spent $8.82 million for development of the Canyon Mine, construction of a wellfield and a header house at the Nichols Ranch Project, and permitting and land holding costs related to these and other projects. While we expect the amounts relative to the items listed above have added future value to the Company, we expense these amounts as we do not have proven or probable reserves at any of the Company's projects under SEC Industry Guide 7. For the year ended December 31, 2016, we spent $21.12 million for development of the Canyon Mine, replacement of leach tanks for the processing of mineralized material at the White Mesa Mill, construction of three wellfields and header houses, the completion of the elution plant at the Nichols Ranch Project, and permitting and land holding costs related to these and other projects. Standby expense The Company’s La Sal and Daneros Projects were placed on standby in 2012, as a result of market conditions. In February 2014, the Company placed its Arizona 1 Project on standby. In 2015 and 2016, the White Mesa Mill was operated at lower levels of uranium recovery, including prolonged periods of standby. Costs related to the care and maintenance of the standby mines, along with standby costs incurred while the White Mesa Mill was operating at low levels of uranium recovery or on standby, are expensed. For the year ended December 31, 2017, standby costs totaled $3.66 million compared with $10.23 million in the prior year. The decrease is primarily related to decreased standby costs incurred due to toll milling activities at the White Mesa Mill during 2017. In 2018 the White Mesa Mill may operate at lower levels of uranium recovery, and excess costs will again be expensed to standby. 124 Abandonment of mineral properties The Company has allocated value to mineral properties upon their acquisition. From time to time, the Company may choose to abandon these mineral properties by not paying the required renewal fees. For the year ended December 31, 2017 the Company did not renew certain mineral leases and recorded abandonment expense of $0.29 million compared with $1.04 million for the year ended December 31, 2016. Accretion Accretion related to the asset retirement obligation for the Company’s properties increased for the year ended December 31, 2017 $1.73 million compared with the prior year $0.91 million primarily due to including a full year of accretion of the Alta Mesa Project which was acquired in June of 2016. Selling, General, and Administrative Selling, general, and administrative expense includes costs associated with marketing uranium, corporate general and administrative costs, and non-cash costs of amortization of above-market sales contract value associated with the acquisition of Denison’s US Mining Division in June 2012 and the Uranerz acquisition in June 2015. General and administrative expenses consist primarily of payroll and related expenses for personnel, contract and professional services, stock-based compensation expense and other overhead expenditures. Selling, general and administrative expenses totaled $18.50 million for the year ended December 31, 2017 compared to $19.22 million for the year ended December 31, 2016. The decrease is a result of the Company's cost cutting measures partially offset by an increase in share based compensation. Impairment The Company, at each reporting date, in accordance with its accounting policy, carries out a review and evaluation of its long- lived assets when events or changes in circumstances indicate that the carrying amounts may not be recoverable. The Company’s estimate of the long term uranium price is one of the factors used to assess whether there is an indication of impairment. The quoted market prices of uranium have fluctuated significantly in the past few years; however, at December 31, 2017, the Company believes the long-term outlook of the uranium industry is positive and expects uranium prices to exceed $60.00 per pound in the future. Accordingly, based on review of our assets including the long-term outlook of the uranium industry, at December 31, 2017, we did not identify any change in circumstances that the carrying amounts of our long-lived assets may not be recoverable. Future uranium prices are uncertain and in the event uranium prices do not meet the Company's expectations, we may have impairments in the future and such impairments may be material. The Company reached the same conclusion in the year ended December 31, 2016. Interest Expense and Other Income and Expenses Interest Expense Interest expense for the year ended December 31, 2017 was $2.10 million compared with $2.29 million in the prior year due to lower principal amounts from the Wyoming revenue bond loan and the put option conversion of the convertible debentures. Other income and expense For the year ended December 31, 2017, other income and expense totaled $2.57 million income. These amounts consist of sales of surplus assets of $1.91 million, a gain for the change in fair value of derivative liabilities of $$0.78 million, a $0.51 million increase in the value of investments accounted at fair value, gains in miscellaneous items of $0.14 million and interest income of $0.16 million partially offset by loss in the mark-to-market values of the Company's debentures of $0.94 million. For the year ended December 31, 2016, other income and expense totaled $1.20 million income. These amounts consist of a gain in value of derivative liabilities of $0.41 million, gains in miscellaneous items of $1.05 million, interest income of $0.14 million partially offset by loss in the mark-to-market values of the Company's debentures of $0.4 million. Results of Operations Year ended December 31, 2016 compared to year ended December 31, 2015 For the year ended December 31, 2016 the Company recorded a net loss of $39.86 million or $0.70 per share compared with a loss of $82.36 million or $2.46 per share for the year ended December 31, 2015. For the year ended December 31, 2016, the Company recorded an operating loss before impairment of $38.77 million compared with an operating loss before impairment of $23.95 million for the year ended December 31, 2015. 125 Revenues The Company’s revenues from uranium are largely based on delivery schedules under long-term contracts, which can vary from quarter to quarter. Revenues for the year ended December 31, 2016 totaled $54.55 million compared with $61.35 million in the year ended December 31, 2015. Revenues for the year ended December 31, 2016 totaled $54.55 million, of which $54.43 million were sales of 1,147,933 pounds of U3O8, which included the sale of 850,000 pounds of U3O8 pursuant to term contracts at an average price of $56.64 per pound and the sale of 297,933 pounds of U3O8 based on spot market prices at an average price of $21.10 per pound. Sales related to the Conventional uranium activities totaled 847,933 pounds of U3O8, of which 750,000 pounds of U3O8 were under long-term contracts at an average price of $54.86 and 97,933 pounds of U3O8 were from spot sales at a price of $26.74 per pound. Included in the sales under contract for the for the year ended December 31, 2016 were 600,000 pounds of U3O8, which were the final contractual deliveries under one of our sales contracts. Sales related to the ISR uranium activities totaled 300,000 pounds of U3O8, of which 100,000 pounds of U3O8 were under long- term contracts at an average price of $70.00 and 200,000 pounds of U3O8 were based on spot sales prices at a price of $18.34 per pound. Revenues for the year ended December 31, 2015 totaled $61.35 million, of which $60.70 million were sales of 1,075,000 pounds of U3O8, which included the sale of 1,025,000 pounds of U3O8 pursuant to term contracts at an average price of $57.39 per pound and the sale of 50,000 pounds of U3O8 on the spot market at a price of $37.35 per pound. Operating Expenses Uranium recovered and costs and expenses applicable to revenue In the year ended December 31, 2016, the Company recovered 1,015,000 pounds of U3O8 of which 335,000 pounds were from the Company's ISR uranium activities and 680,000 pounds were from the Company's Conventional uranium activities. The Conventional uranium activities included recovery of 249,000 pounds from alternate feed sources and 431,000 pounds from conventional feed material. In the year ended December 31, 2015, the Company recovered 468,000 pounds of U3O8 of which 72,000 pounds of U3O8 were for the account of a third party under processing agreements. Uranium recovered for its own account included approximately 172,000 pounds from its new ISR uranium activities for the period from acquisition (June 18, 2015 through December 31, 2015), 199,000 pounds from alternate feed sources and 25,000 pounds from conventional feed material from our Conventional uranium activities. Costs and expenses applicable to revenue for the year ended December 31, 2016 totaled $35.45 million, compared with $37.62 million for the year ended December 31, 2015. The decrease in the cost of sales was primarily attributable to a decrease in average cost per pound partially offset by an increase in the quantity of U3O8 sold year over year as discussed above. Costs of goods sold averaged $30.88 per pound and $34.99 per pound in the years ended December 31, 2016 and 2015, respectively. Other operating costs and expenses Development, permitting and land holding For the year ended December 31, 2016, the Company spent $21.12 million for development of the Canyon Mine, replacement of leach tanks for the processing of mineralized material at the White Mesa Mill, construction of three wellfields and header houses and the completion of the elution plant at the Nichols Ranch Project and permitting and land holding costs related to these and other projects. While we expect the amounts expensed relative to the items listed above have added future value to the Company, we expense these amounts as we do not have proven or probable reserves at any of the Company's projects under SEC Industry Guide 7. For the year ended December 31, 2015, we spent $8.76 million primarily on permitting, wellfield construction and partial construction of the elution circuit at our Nichols Ranch Project. Standby expense The Company’s La Sal and Daneros Projects were placed on standby in the last quarter of calendar year 2012, as a result of market conditions. In February 2014, the Company placed its Arizona 1 Project on standby. In 2015 and 2016, the White Mesa Mill was operated at lower levels of uranium recovery, including prolonged periods of standby. Costs related to the care and maintenance of the standby mines, along with standby costs incurred while the White Mesa Mill was operating at low levels of uranium recovery or on standby, are expensed. 126 For the year ended December 31, 2016, standby costs totaled $10.23 million compared with $10.77 million in the prior year. The decrease is primarily related to decreased standby costs at the White Mesa Mill partially offset by holding costs for Alta Mesa. The White Mesa Mill operated a conventional campaign during third quarter of 2016 which resulted in a decreased amount of time the White Mesa Mill was on standby and higher uranium recovery levels. Abandonment of mineral properties The Company has allocated value to mineral properties upon their acquisition. From time to time, the Company may choose to abandon these mineral properties by not paying the required renewal fees. For the year ended December 31, 2016 the Company did not renew certain mineral leases and recorded abandonment expense of $1.04 million compared with $2.77 million for the year ended December 31, 2015. Accretion Accretion related to the asset retirement obligation for the Company’s properties increased for the year ended December 31, 2016 $0.91 million compared with the prior year $0.49 million primarily due to the increase in the amount of the asset retirement obligation added in connection with the Alta Mesa acquisition and a full year of accretion related to the Nichols Ranch Project acquired in June of 2015. Selling, General, and Administrative Selling, general, and administrative expense includes costs associated with marketing uranium, corporate general and administrative costs, and non-cash costs of amortization of above-market sales contract value associated with the acquisition of Denison’s US Mining Division in June 2012 and the Uranerz acquisition in June 2015. General and administrative expenses consist primarily of payroll and related expenses for personnel, contract and professional services, stock-based compensation expense and other overhead expenditures. Selling, general and administrative expenses totaled $19.22 million for the year ended December 31, 2016 compared to $24.89 million for the year ended December 31, 2015. The decrease is a result of lower amortization of intangible asset amortization as a result of the lower level of term sales discussed above, absence of costs related to the acquisition of Uranerz in 2015 ($6.89 million) offset by an overall increase in the level of general and administrative expense due to the increase in the size of the organization resulting from the acquisitions. Impairment On June 18, 2015, the Company recorded goodwill of $47.73 million associated with the acquisition of Uranerz on that date. The goodwill was a result of the value of the equity consideration given up to acquire Uranerz, which was in excess of the value of the assets acquired, net of obligations assumed and was valued at the closing price on the day of the acquisition ($4.16 per share). In the period following the acquisition of Uranerz to December 31, 2015, the uranium spot market price fell around 20% and the value of our shares and related market capitalization decreased significantly due to a number of factors. As a result, the Company evaluated the acquisition value of the goodwill at December 31, 2015, based on its annual impairment test for goodwill, and determined that the goodwill should be fully impaired. Also, in the year ended December 31, 2015, the Company made the decision to sell or abandon certain non-core mineral resource properties that it felt were not essential to its future operations in order to save costs and/or receive value for these properties. These properties are currently being marketed for sale or have already been sold. A total of $8.22 million of our mineral resource properties were impaired based on our review of the properties and their associated carrying values. Interest Expense and Other Income and Expenses Interest Expense Interest expense for the year ended December 31, 2016 was $2.29 million compared with $2.04 million in the prior year. Other income and expense For the year ended December 31, 2016, other income and expense totaled $1.20 million income. These amounts consist of a gain in value of derivative liabilities of $0.41 million, gains in miscellaneous items of $1.05 million, interest income of $0.14 million partially offset by loss in the mark-to-market values of the Company's debentures of $0.4 million. Other income and expense for the year ended December 31, 2015 totaled $0.42 million expense and consisted of a change in the mark-to-market values of the Company’s Debentures totaling $1.55 million partially offset by a change in the value of derivative liabilities related to warrants of $0.59 million and other income amounts totaling $0.54 million. 127 LIQUIDITY AND CAPITAL RESOURCES Funding of major business and property acquisitions Over the past six years the Company has funded major business and property acquisitions with capital provided by issuance of its common shares. In 2012 we acquired Titan Uranium Inc. and the US Mining Division of Denison, in 2013 we acquired Strathmore Minerals Corp, in 2015 we acquired Uranerz and in 2016 we acquired Mesteña, each in exchange for newly issued shares. We intend to continue to acquire assets utilizing common shares when we can do so under attractive terms. Cash issued for shares On December 23, 2016, the Company filed a prospectus supplement in both Canada and the United States to its Canadian base shelf prospectus and U.S. registration statement on Form S-3 which enabled the Company, at its discretion from time to time, to sell up to $20 million worth of Common Shares by way of an “at-the-market” offering (the “ATM”). From January 1, 2017 to March 9, 2018, a total of 7,591,949 Common Shares have been sold under the ATM, for net proceeds to the Company of $14.83 million. On December 29, 2017, the Company filed a prospectus supplement to its U.S. registration statement, qualifying for distribution up to $30.00 million in additional common shares under the ATM. Working capital at December 31, 2017 and future requirements for funds At December 31, 2017, the Company had working capital of $33.30 million, including $18.57 million in cash and 595,000 pounds of finished goods inventory. The Company believes it has sufficient cash and resources to carry out its business plan for at least the next twelve months. The Company is actively focused on its forward looking liquidity needs, especially in light of the current depressed uranium markets. The Company is evaluating its ongoing fixed cost structure as well as decisions related to project retention, advancement and development. If current uranium prices persist for any extended period of time, the Company will likely be required to raise capital or take other measures to fund its ongoing operations. Significant development activities, if warranted, will require that we arrange for financing in advance of planned expenditures. In addition, we expect to continue to augment our current financial resources with external financing as our long term business needs require. The Company manages liquidity risk through the management of its capital structure. Accounts payable and accrued liabilities, current portion of notes payable and current taxes payable are due within the current operating year. Cash and cash flows Year ended December 31, 2017 Cash and cash equivalents were $18.57 million at December 31, 2017, compared to $16.90 million at December 31, 2016. The increase of $1.67 million was due primarily to cash provided by financing activities of $10.42 million, cash provided in investing activities of $1.05 million, gain on foreign exchange on cash held of $0.54 million, partially offset by cash used in operations of $10.34 million. Net cash provided by financing activities totaled $10.42 million consisting primarily of $14.15 million proceeds from the issuance of stock using the Company's ATM offering, and cash received from non-controlling interests of $0.37 million, partially offset by $4.10 million to repay loans and borrowings. Net cash used in operating activities of $10.34 million is comprised of the net loss of $27.99 million for the period adjusted for non-cash items and for changes in working capital items. Significant items not involving cash were $4.64 million of depreciation and amortization of property, plant and equipment, shared based compensation of $3.53 million, $3.31 million impairment on inventory, impairment of mineral properties held for sale of $3.80 million, accretion of ARO of $1.73 million, offset by a $1.41 million decrease in accounts payable and accrued liabilities, $0.78 million change in warrant liabilities and $0.74 million in cash paid for reclamation and remediation activities. Net cash provided by investing activities was $1.05 million, which was from receipts of additional refunded cash previously deposited with regulatory agencies. Year ended December 31, 2016 Cash and cash equivalents were $16.90 million at December 31, 2016, compared to $12.97 million at December 31, 2015. The increase of $3.93 million was due primarily to cash provided by financing activities of $22.18 million, partially offset by cash used in operations of $12.04 million, cash used in investing activities of $6.27 million. 128 Net cash provided by financing activities totaled $22.18 million consisting primarily of $25.29 million proceeds from the issuance of stock in the March 2016, September 2016 public offerings, ATM and for exercise of options and warrants, cash received from non-controlling interests of $0.04 million, partially offset by $3.17 million to repay loans and borrowings. Net cash used in operating activities of $12.04 million is comprised of the net loss of $39.86 million for the period adjusted for non-cash items and for changes in working capital items. Significant items not involving cash were $4.26 million of depreciation and amortization of property, plant and equipment, adjustment to asset retirement obligation of $4.19 million, $5.36 million impairment on inventory, $1.04 million abandonment of mineral properties, a $13.16 million decrease in inventories, $2.40 million decrease in trade and other receivables offset by a $4.01 million decrease in accounts payable and accrued liabilities and $2.09 million in cash paid for reclamation and remediation activities. Net cash used by investing activities was $6.27 million, which was primarily related to expenditures for the Alta Mesa acquisition net of cash acquired of $1.29 million and cash expenditures related to additional cash deposited with regulatory agencies of $5.66 million offset by cash received from the sale of mineral properties held for sale of $0.85 million. Contractual Obligations The following table summarizes our contractual obligations as of December 31, 2017. Payments due by period - $000 Less than 1 More than Total year 1 - 3 years 3 - 5 years 5 years Long-term debt obligations - principal payable in cash Interest on long-term debt obligations Operating lease obligations Purchase obligations Deferred income Decommissioning liabilities (undiscounted) Subtotal - payable in cash Long-term obligations - principal payable in cash or common shares at Company discretion Total contractual obligations $ 10,855 $ 3,414 $ 7,441 $ — $ 3,727 1,836 48 2,339 43,457 62,262 16,636 1,491 407 41 — 32 5,385 2,236 588 7 — 4,495 14,767 16,636 — 694 — — 3,440 4,134 — — 147 — 2,339 35,490 37,976 $ 78,898 $ 5,385 $ 31,403 $ 4,134 $ 37,976 In addition, the Company entered into commitments with federal and state agencies and private individuals to lease surface and mineral rights. These leases are renewable annually and are expected to total $1.00 million for the year ended December 31, 2018. Critical accounting estimates and judgments The preparation of these consolidated financial statements in accordance with US GAAP requires the use of certain critical accounting estimates and judgments that affect the amounts reported. It also requires management to exercise judgment in applying the Company’s accounting policies. These judgments and estimates are based on management’s best knowledge of the relevant facts and circumstances taking into account previous experience. Although the Company regularly reviews the estimates and judgments made that affect these financial statements, actual results may be materially different. Significant estimates made by management include: a. Exploration Stage SEC Industry Guide 7 defines a reserve as “that part of a mineral deposit which could be economically and legally extracted or produced at the time of the reserve determination”. The classification of a reserve must be evidenced by a bankable feasibility study using the latest three-year price average. While the Company has established the existence of mineral resources and has successfully extracted and recovered saleable uranium from certain of these resources, the Company has not established proven or probable reserves, as defined under SEC Industry Guide 7, for these operations or any of its uranium projects. As a result, the Company is in the Exploration Stage as defined under Industry Guide 7. Furthermore, the Company has no plans to establish proven or probable reserves for any of its uranium projects. While in the Exploration Stage, among other things, the Company must expense all amounts that would normally be capitalized and subsequently depreciated or depleted over the life of the mining operation on properties that have proven or probable reserves. 129 Items such as the construction of wellfields and related header houses, additions to our recovery facilities and advancement of properties will all be expensed in the period incurred. As a result, the Company’s consolidated financial statements may not be directly comparable to the financial statements of mining companies in the development or production stages. b. Resource estimates utilized The Company utilizes estimates of its mineral resources based on information compiled by appropriately qualified persons. The information relating to the geological data on the size, depth and shape of the deposits requires complex geological judgments to interpret the data. The estimation of future cash flows related to resources is based upon factors such as estimates of future uranium prices, future construction and operating costs along with geological assumptions and judgments made in estimating the size and grade of the resource. Changes in the mineral resource estimates may impact the carrying value of mining and recovery assets, goodwill, reclamation and remediation obligations and depreciation and impairment. c. Valuation of mining and recovery assets in a business combination We value assets in a business combination based on our estimates of the fair value of the mining and recovery assets acquired. For mining and recovery assets actively extracting and recovering uranium as well as those assets that we expect to extract uranium from, we value the assets based on the income approach. As we have not acquired proven or probable reserves in our business combinations the value ascribed to these assets is based on our estimates of value beyond proven and probable reserves. The value is calculated based, in part, on technical reports prepared under NI 43-101. Our estimates of extraction and recovery activities and related timing of extraction and recovery as well as the costs involved are demonstrated by at least a preliminary economic assessment. We then adjust the results of the technical reports to include the effects of anticipated fluctuations in the future market price of uranium consistent with what we believe to be the expectations of other market participants as well as any expected operational or cost changes that we expect in the future operations of these mining assets. These cash flow estimates include the estimated cash outflows to develop, extract and recover the estimated saleable U3O8 from these operations. For mining assets that will be held for further evaluation or for sale, we use the market approach utilizing implied transaction multiples from historical uranium interests transactions. d. Valuation of mining assets acquired other than in a business combination The costs of mining assets that are acquired in an asset purchase transaction are recorded as mineral interests on the date of purchase based on the consideration given up for the assets. If multiple assets are involved in a transaction, the consideration is allocated based on the relative values of the properties acquired. e. Depreciation of mining and recovery assets acquired For mining and recovery assets actively extracting and recovering uranium we depreciate the acquisition costs of the mining and recovery assets on a straight line basis over our estimated lives of the mining and recovery assets. The process of estimating the useful life of the mining and recovery assets requires significant judgment in evaluating and assessing available geological, geophysical, engineering and economic data, projected rates of extraction and recovery, estimated commodity price forecasts and the timing of future expenditures, all of which are, by their very nature, subject to interpretation and uncertainty. Changes in these estimates may materially impact the carrying value of the Company’s mining and recovery assets and the recorded amount of depreciation. f. Business combinations Management uses judgment in applying the acquisition method of accounting for business combinations and in determining fair values of the identifiable assets and liabilities acquired. The value placed on the acquired assets and liabilities, including identifiable intangible assets, will have an effect on the amount of goodwill or bargain purchase gain that the Company may record on an acquisition. Changes in economic conditions, commodity prices and other factors between the date that an acquisition is announced and when it finally is consummated can have a material difference on the allocation used to record a preliminary purchase price allocation versus the final purchase price allocation which can take up to one year after acquisition to complete. See b. above for information related to the valuation of mining and recovery assets in this process. 130 g. Impairment testing of mining and recovery assets The Company undertakes a review of the carrying values of its mining and recovery assets whenever events or changes in circumstances indicate that their carrying values may exceed their estimated net recoverable amounts determined by reference to estimated future operating results and net cash flows. An impairment loss is recognized when the carrying value of a mining or recovery asset is not recoverable based on this analysis. In undertaking this review, the management of the Company is required to make significant estimates of, among other things, future production and sale volumes, forecast commodity prices, future operating and capital costs and reclamation costs to the end of the mining asset’s life. These estimates are subject to various risks and uncertainties, which may ultimately have an effect on the expected recoverability of the carrying values of mining and recovery assets. h. Asset retirement obligations Asset retirement obligations are recorded as a liability when an asset that will require reclamation and remediation is initially acquired. For disturbances created on a property owned that will require future reclamation and remediation the Company records asset retirement obligations for such disturbance when occurred. The Company has accrued its best estimate of its share of the cost to decommission its mining and milling properties in accordance with existing laws, contracts and other policies. The estimate of future costs involves a number of estimates relating to timing, type of costs, mine closure plans, and review of potential methods and technical advancements. Furthermore, due to uncertainties concerning environmental remediation, the ultimate cost of the Company’s decommissioning liability could differ from amounts provided. The estimate of the Company’s obligation is subject to change due to amendments to applicable laws and regulations and as new information concerning the Company’s operations becomes available. The Company is not able to determine the impact on its financial position, if any, of environmental laws and regulations that may be enacted in the future. Additionally, the expected cash flows in the future are discounted at the Company’s estimated cost of capital based on the periods the Company expects to complete the reclamation and remediation activities. Differences in the expected periods of reclamation or in the discount rates used could have a material difference in the actual settlement of the obligations compared with the amounts provided ITEM 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK The Company is exposed to risks associated with commodity prices, interest rates and credit. Commodity price risk is defined as the potential loss that we may incur as a result of changes in the market value of uranium. Interest rate risk results from our debt and equity instruments that we issue to provide financing and liquidity for our business. Credit risk arises from the extension of credit throughout all aspects of our business. Industry-wide risks can also affect our general ability to finance exploration, and development of exploitable resources; such effects are not predictable or quantifiable. Market risk is the risk to the Company of adverse financial impact due to change in the fair value or future cash flows of financial instruments as a result of fluctuations in interest rates and foreign currency exchange rates. Commodity Price Risk The Company is subject to market risk related to the market price of U3O8. Two of our four supply contracts contain favorable pricing above current spot prices; however, these long term prices cover only a portion of our planned uranium recovery. The Company's existing long term contracts expire following the Company's 2018 deliveries, and all uranium sales after 2018 will be required to be made at spot prices until the Company enters into new long-term contracts at satisfactory prices in the future. Revenue beyond our current contracts will be affected by both spot and long-term U3O8 price fluctuations which are beyond our control, including: the demand for nuclear power; political and economic conditions; governmental legislation in uranium producing and consuming countries; and production levels and costs of production of other producing companies. The Company continuously monitors the market to determine its level of extraction and recovery of uranium in the future. Interest Rate Risk The Company is exposed to interest rate risk on its cash equivalents, deposits, restricted cash, and debt. Our interest earned is not material; thus not subject to significant risk. Our Wyoming Industrial Development Revenue Bond has a fixed interest rate over its remaining four year life, removing variability. The Company is exposed to an interest rate risk associated with the Debentures, which is based on the spot market price of U3O8. These debentures mature in December 2020. The Company does not expect the spot market price of U3O8 to exceed $54.99 prior to the debentures’ maturity and, accordingly, does not believe there is any significant interest rate risk related to these debentures. The Company does not use derivatives to manage interest rate risk. The following chart displays the interest rate applicable to our convertible debentures at various U3O8 price levels. 131 UxC U3O8 Weekly Indicator Price Up to $54.99 $55.00–$59.99 $60.00–$64.99 $65.00–$69.99 $70.00–$74.99 $75.00–$79.99 $80.00–$84.99 $85.00–$89.99 $90.00–$94.99 $95.00–$99.99 $100 and above Annual Interest Rate 8.5% 9% 9.5% 10% 10.5% 11% 11.5% 12% 12.5% 13% 13.5% Currency Risk The foreign exchange risk relates to the risk that the value of financial commitments, recognized assets or liabilities will fluctuate due to changes in foreign currency rates. The Company does not use any derivative instruments to reduce its exposure to fluctuations in foreign currency exchange rates. As the US Dollar is the functional currency of our U.S. operations, the currency risk has been reduced. We maintain a nominal balance in foreign currency, resulting in a low currency risk relative to our cash balances. Our Debentures are denominated in Canadian Dollars and, accordingly, are exposed to currency risk. The following table summarizes, in United States dollar equivalents, the Company’s major foreign currency (Cdn$) exposures as of December 31, 2017 ($000): Cash and cash equivalents Accounts payable and accrued liabilities Loans and borrowings Total $ $ 6,128 (531) (16,636) (11,039) The table below summarizes a sensitivity analysis for significant unsettled currency risk exposure with respect to our financial instruments as at December 31, 2017 with all other variables held constant. It shows how net income would have been affected by changes in the relevant risk variables that were reasonably possible at that date. ('000s) Change for Sensitivity Analysis Increase (decrease) in other comprehensive income Strengthening net earnings Weakening net earnings Credit Risk +1% change in U.S. dollar $ -1% change in U.S. dollar $ (138) 138 Credit risk relates to cash and cash equivalents, trade, and other receivables that arise from the possibility that any counterparty to an instrument fails to perform. The Company only transacts with highly-rated counterparties and a limit on contingent exposure has been established for any counterparty based on that counterparty’s credit rating. The Company’s sales are attributable mainly to large utilities. As at December 31, 2017, the Company’s maximum exposure to credit risk was the carrying value of cash and cash equivalents and trade receivables. 132 ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA ENERGY FUELS INC. CONSOLIDATED FINANCIAL STATEMENTS December 31, 2017 Contents Report of Independent Registered Public Accounting Firms Financial Statements: Consolidated Statements of Operations and Comprehensive Loss for the years ended December 31, 2017, December 31, 2016 and December 31, 2015 Consolidated Balance Sheets at December 31, 2017 and December 31, 2016 Consolidated Statements of Changes in Equity for the years ended December 31, 2017, December 31, 2016 and December 31, 2015 Consolidated Statements of Cash Flows for the years ended December 31, 2017, December 31, 2016 and December 31, 2015 Notes to the Consolidated Financial Statements F-1 F-2 F-3 F-4 F-5 F-6 133 REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM The Shareholders and Board of Directors Energy Fuels Inc.: Opinion on the Consolidated Financial Statements We have audited the accompanying consolidated balance sheet of Energy Fuels Inc. (the Company) as of December 31, 2017, the related consolidated statements of operations and comprehensive loss, changes in equity, and cash flows for the year ended December 31, 2017, and the related notes (collectively, the consolidated financial statements). In our opinion, the consolidated financial statements present fairly, in all material respects, the financial position of the Company as of December 31 2017, and the results of its operations and its cash flows for the year ended December 31, 2017, in conformity with U.S. generally accepted accounting principles. Basis for Opinion These consolidated financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on these consolidated financial statements based on our audit. We are a public accounting firm registered with the Public Company Accounting Oversight Board (United States) (PCAOB) and are required to be independent with respect to the Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB. We conducted our audit in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the consolidated financial statements are free of material misstatement, whether due to error or fraud. The Company is not required to have, nor were we engaged to perform, an audit of its internal control over financial reporting. As part of our audit, we are required to obtain an understanding of internal control over financial reporting but not for the purpose of expressing an opinion on the effectiveness of the Company’s internal control over financial reporting. Accordingly, we express no such opinion. Our audit included performing procedures to assess the risks of material misstatement of the consolidated financial statements, whether due to error or fraud, and performing procedures that respond to those risks. Such procedures included examining, on a test basis, evidence regarding the amounts and disclosures in the consolidated financial statements. Our audit also included evaluating the accounting principles used and significant estimates made by management, as well as evaluating the overall presentation of the consolidated financial statements. We believe that our audit provides a reasonable basis for our opinion. We have served as the Company’s auditor since 2017. /s/ KPMG LLP Denver, Colorado March 9, 2018 134 To the Board of Directors and Shareholders Energy Fuels Inc.: We have audited the accompanying consolidated balance sheet of Energy Fuels Inc. as of December 31, 2016, and the related consolidated statements of operations and comprehensive loss, changes in equity, and cash flows for each of the years in the two-year period ended December 31, 2016. These consolidated financial statements are the responsibility of Energy Fuels Inc.'s management. Our responsibility is to express an opinion on these consolidated financial statements based on our audits. We conducted our audits in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. An audit includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements. An audit also includes assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audits provide a reasonable basis for our opinion. In our opinion, the consolidated financial statements referred to above present fairly, in all material respects, the financial position of Energy Fuels Inc. as of December 31, 2016, and the results of its operations and its cash flows for each of the years in the two-year period ended December 31, 2016, in conformity with U.S. generally accepted accounting principles. Chartered Professional Accountants, Licensed Public Accountants /s/ KPMG LLP March 8, 2017 Toronto, Canada 135 ENERGY FUELS INC. Consolidated Statements of Operations and Comprehensive Loss (Expressed in thousands of US dollars, except per share amounts) Revenues Uranium concentrates Alternate feed materials processing and other Total revenues Costs and expenses applicable to revenue Costs and expenses applicable to uranium concentrates Costs and expenses applicable to alternate feed materials and other Total costs and expenses applicable to revenue Impairment of inventories Development, permitting and land holding Standby costs Abandonment of mineral properties Impairment of assets held for sale Accretion of asset retirement obligation Selling costs Intangible asset amortization General and administration Costs directly attributable to acquisitions Impairment of plant and equipment and mineral properties Impairment of goodwill Total operating loss Interest expense Other income (expense) Net loss Items that may be reclassified in the future to profit and loss Foreign currency translation adjustment Unrealized gain/(loss) on available-for-sale assets Other comprehensive income (loss) Comprehensive loss Net loss attributable to: Owners of the Company Non-controlling interests Comprehensive loss attributable to: Owners of the Company Non-controlling interests Basic and diluted loss per share See accompanying notes to the consolidated financial statements. 136 For the years ended December 31, 2017 2016 2015 $ 24,467 $ 6,579 31,046 14,676 4,729 19,405 3,305 8,821 3,659 287 3,799 1,733 275 3,297 14,923 — — — 54,432 $ 120 54,552 35,315 138 35,453 5,362 21,118 10,234 1,036 — 906 379 3,319 15,519 — — — 60,696 655 61,351 37,384 233 37,617 — 8,762 10,765 2,770 — 494 316 5,364 12,325 6,886 8,224 47,730 (28,458) (38,774) (79,902) (2,101) 2,569 (27,990) (2,289) 1,199 (39,864) (2,035) (420) (82,357) (1,049) 30 (1,019) (729) 532 (197) 3,056 (136) 2,920 (29,009) $ (40,061) $ (79,437) (27,766) $ (224) (39,413) $ (451) (82,217) (140) (27,990) $ (39,864) $ (82,357) (28,785) $ (224) (39,610) $ (451) (79,297) (140) (29,009) $ (40,061) $ (79,437) (0.39) $ (0.70) $ (2.46) $ $ $ $ $ $ ENERGY FUELS INC. Consolidated Balance Sheets (Expressed in thousands of US dollars, except share amounts) ASSETS Current assets Cash and cash equivalents Trade and other receivables, net Inventories, net Prepaid expenses and other assets Mineral properties held for sale Total current assets Investments accounted for at fair value Plant and equipment, net Mineral properties, net Intangible assets, net Restricted cash Total assets LIABILITIES & EQUITY Current liabilities Accounts payable and accrued liabilities Current portion of asset retirement obligation Current portion of loans and borrowings Total current liabilities Warrant liabilities Deferred revenue Asset retirement obligation Loans and borrowings Total liabilities Equity Share capital Common shares, without par value, unlimited shares authorized; shares issued and outstanding 74,366,824 at December 31, 2017 and 66,205,153 at December 31, 2016 Accumulated deficit Accumulated other comprehensive income Total shareholders' equity Non-controlling interests Total equity Total liabilities and equity Commitments and contingencies (Note 18) See accompanying notes to the consolidated financial statements. 137 December 31, 2017 December 31, 2016 $ 18,574 $ 1,253 16,550 1,814 5,000 43,191 903 33,076 83,539 2,502 22,127 16,901 364 16,761 2,104 — 36,130 1,146 37,582 92,625 5,799 23,175 $ 185,338 $ 196,457 $ 6,449 $ 32 3,414 9,895 3,376 2,474 18,248 24,077 58,070 430,383 (309,287) 2,289 123,385 3,883 127,268 $ 185,338 $ 5,756 32 6,319 12,107 3,912 2,339 17,001 23,235 58,594 412,334 (281,521) 3,308 134,121 3,742 137,863 196,457 ENERGY FUELS INC. Consolidated Statements of Changes in Equity (Expressed in thousands of US dollars, except share amounts) Common Stock Shares Amount Deficit Accumulated other comprehensive income Total shareholders' equity Non- controlling interests Total equity Balance at December 31, 2014 19,677,552 $ 260,117 $ (159,891) $ 585 $ 100,811 $ — $ 100,811 Net loss Other comprehensive income Shares issued in connection with the acquisition of Uranerz Energy Corporation Options issued in connection with the acquisition of Uranerz Energy Corporation Shares issued for cash by at-the- market offering Share issued for property acquisitions Shares issued for exercise of stock options Shares issued for exercise of share purchase warrants Share issuance cost Share-based compensation Non-controlling interest upon acquisition of Uranerz Energy Corporation Contributions attributable to non-controlling interest — — — — 25,347,209 105,673 — 3,681 1,275,908 2,939 169,361 48,802 300 — — — — 550 185 2 (312) 1,099 — — (82,217) — — — — — — — — — — — — 2,920 — — — — — — — — — — (82,217) 2,920 105,673 3,681 2,939 550 185 2 (312) 1,099 — — (140) (82,357) — — — — — — — — — 2,920 105,673 3,681 2,939 550 185 2 (312) 1,099 3,992 3,992 304 304 Balance at December 31, 2015 46,519,132 $ 373,934 $ (242,108) $ 3,505 $ 135,331 $ 4,156 $ 139,487 Net loss Other comprehensive income Shares issued for cash by at-the- market offering — — 200,225 — — 539 Shares issued for public offerings Share issuance cost Share-based compensation Shares issued for exercise of stock options Shares issued for the vesting of restricted stock units Shares issued for acquisition of Alta Mesa Shares issued for acquisition of 40% interest in Roca Honda Shares issued for consulting services Contributions attributable to non-controlling interest 13,368,750 22,980 — — 8,369 138,608 (2,330) 2,657 18 — 4,551,284 11,378 1,212,173 2,679 206,612 — 479 — (39,413) — — — — — — — — — — — — (197) — — — — — — — — — — (39,413) (197) 539 22,980 (2,330) 2,657 18 — 11,378 2,679 479 — (451) (39,864) — — — — — — — — — — 37 (197) 539 22,980 (2,330) 2,657 18 — 11,378 2,679 479 37 Balance at December 31, 2016 66,205,153 $ 412,334 $ (281,521) $ 3,308 $ 134,121 $ 3,742 $ 137,863 Net loss Other comprehensive income Shares issued for cash by at-the- market offering Shares issued for the vesting of restricted stock units Share issuance cost — — — — 7,202,479 14,548 752,580 — — (394) (27,766) — — — — 138 — (1,019) — — — (27,766) (1,019) 14,548 — (394) (224) — — — — (27,990) (1,019) 14,548 — (394) Share-based compensation Shares issued for consulting services Contributions attributable to non-controlling interest — 3,525 206,612 — 370 — — — — — — — 3,525 370 — — — 365 3,525 370 365 Balance at December 31, 2017 74,366,824 $ 430,383 $ (309,287) $ 2,289 $ 123,385 $ 3,883 $ 127,268 See accompanying notes to the consolidated financial statements. 139 ENERGY FUELS INC. Consolidated Statements of Cash Flows (Expressed in thousands of US dollars) OPERATING ACTIVITIES Net loss for the period Items not involving cash: Depletion, depreciation and amortization Stock-based compensation Change in value of convertible debentures Accretion of asset retirement obligation Change in value of warrant liabilities Unrealized foreign exchange (gain) loss Non-cash standby cost accrued Non-cash costs directly attributable to acquisitions Impairment of inventories Abandonment of mineral properties Impairment of goodwill Impairment of property, plant and equipment and mineral properties Impairment of mineral properties held for sale Change in value of investments Other non- cash (income) expense Changes in assets and liabilities Decrease in inventories (Increase) decrease in trade and other receivables (Increase) decrease in prepaid expenses and other assets Increase (decrease) in accounts payable and accrued liabilities Changes in deferred revenue Cash paid for reclamation and remediation activities INVESTING ACTIVITIES Purchase of mineral properties and property, plant and equipment Acquisition of Uranerz Energy Corporation, net of cash acquired Acquisition of Alta Mesa, net of cash acquired Acquisition of Roca Honda, net of cash acquired Change in cash deposited with regulatory agencies for asset retirement obligations Proceeds from sale of mineral properties December 31, 2017 December 31, 2016 December 31, 2015 $ (27,990) $ (39,864) $ (82,357) 4,636 3,525 940 1,733 (784) (263) 249 — 3,305 287 — — 3,799 — 1,909 73 (39) 290 (1,410) 135 (735) 4,258 2,657 407 906 — 173 4,186 — 5,362 1,036 — — — — (437) 13,158 2,403 (365) (4,007) 174 (2,086) (10,340) (12,039) — — — — 1,048 — 1,048 (260) — (1,290) 101 (5,663) 845 (6,267) 7,787 1,099 1,548 494 — 483 877 3,928 — 2,770 47,730 8,224 — (38) (500) 5,751 (2,017) (404) 2,519 648 (626) (2,084) (4,297) 2,459 — — 5,268 — 3,430 140 FINANCING ACTIVITIES Issuance of common shares and warrants for cash Option and warrant exercises Repayment of loans and borrowings Cash received from non-controlling interest INCREASE IN CASH AND CASH EQUIVALENTS DURING THE PERIOD Effect of exchange rate fluctuations on cash held in foreign currencies Cash and cash equivalents - beginning of period 14,154 — (4,095) 365 10,424 1,132 541 16,901 25,291 18 (3,168) 37 22,178 3,872 64 2,627 187 (1,730) 304 1,388 2,734 (180) 12,965 10,411 CASH AND CASH EQUIVALENTS - END OF PERIOD $ 18,574 $ 16,901 $ 12,965 Non-cash investing and financing transactions: Issuance of secured notes for acquisition of mineral properties Issuance of common shares for acquisition of mineral properties Issuance of common shares, options and warrants for acquisition of Uranerz Energy Corporation Issuance of common shares for acquisition of Alta Mesa Issuance of common shares for acquisition of 40% interest in Roca Honda Issuance of common shares for consulting services $ — $ — $ 446 550 — — — 370 — 109,354 11,378 2,679 479 — — — Supplemental disclosure of cash flow information: Net cash paid during the period for: Interest See accompanying notes to the consolidated financial statements. 2,097 2,029 1,460 141 ENERGY FUELS INC. NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS FOR THE THREE YEARS ENDED DECEMBER 31, 2017 (Tabular amounts expressed in thousands of US Dollars except share and per share amounts) 1. THE COMPANY AND DESCRIPTION OF BUSINESS Energy Fuels Inc. was incorporated under the laws of the Province of Alberta and was continued under the Business Corporations Act (Ontario). Energy Fuels Inc. and its subsidiary companies (collectively “the Company” or “EFI”) are engaged in uranium extraction, recovery and sales of uranium from mineral properties and the recycling of uranium bearing materials generated by third parties. As a part of these activities the Company also acquires, explores, evaluates and, if warranted, permits uranium properties. The Company’s final uranium product, uranium oxide concentrates (“U3O8” or “uranium concentrates”), is sold to customers for further processing into fuel for nuclear reactors. The Company is an exploration stage mining company as defined by the United States (“U.S.”) Securities and Exchange Commission (“SEC”) Industry Guide 7 (“SEC Industry Guide 7”) as it has not established the existence of proven or probable reserves on any of our properties. Energy Fuels is engaged in conventional and In-situ ("ISR") uranium extraction and recovery, along with the exploration, permitting and evaluation of uranium properties in the United States. Mining activities Mining activities consist of a standalone uranium recovery facility (the “White Mesa Mill”), an ISR recovery facility, conventional mining projects and ISR mining projects. The conventional projects are located in the Colorado Plateau, Henry Mountains, Arizona Strip, and the Roca Honda project in New Mexico which are in the vicinity of the White Mesa Mill, and the Sheep Mountain Project in Wyoming. ISR projects include the Nichols Ranch Project, the Jane Dough property and the Hank Project located in Wyoming and the Alta Mesa ISR Project (the “Alta Mesa Project”) located in Texas. At December 31, 2017, other than shaft-sinking and evaluation work at the Company's Canyon Project, the conventional mining projects in the vicinity of the White Mesa Mill and Sheep Mountain are on standby, being evaluated for continued mining activities and/or in process of being permitted. The White Mesa Mill also processes third party uranium bearing mineralized materials from mining and recycling activities. 2. BASIS OF PRESENTATION The consolidated financial statements have been prepared in accordance with accounting principles generally accepted in the United States (“U.S. GAAP”) and are presented in thousands of US dollars (“USD”) except per share amounts. Certain footnote disclosures have share prices which are presented in Canadian dollars (“Cdn$”). 3. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES Use of estimates The Company's consolidated financial statements have been prepared in accordance with U.S. GAAP. The preparation of the Company's consolidated financial statements requires the Company to make estimates and assumptions that affect the reported amounts of assets and liabilities and the related disclosure of contingent assets and liabilities at the date of the consolidated financial statements and the reported amounts of expenses during the reporting period. The more significant areas requiring the use of management estimates and assumptions relate to expectations of the future price of uranium and estimates of recoverable mineral resources that are the basis for future cash flow estimates utilized in assessing fair value for business combinations and impairment calculations; the determination of whether an acquisition represents a business combination or an asset acquisition; the use of management estimates and assumptions related to environmental, reclamation and closure obligations; marketable securities and derivative instruments; and stock-based compensation expense. Actual results may differ significantly from these estimates. Basis of consolidation These consolidated financial statements include the accounts of the Company together with subsidiaries controlled by the Company. Intercompany transactions, balances and unrealized gains on transactions between the Company and its subsidiaries are eliminated. The functional currency of the Company’s operations is the USD. 142 Extracting and recovery activities while in the exploration stage The Company extracts or recovers mineralized uranium from mining activities, and alternate feed materials, resulting in saleable uranium concentrates from its White Mesa Mill and its Nichols Ranch Project. While the Company has established the existence of mineral resources and extracts and processes saleable uranium from these operations, the Company has not established proven or probable reserves, as defined under SEC Industry Guide 7, for these operations or any of its uranium projects. Furthermore, the Company has no current plans to establish proven or probable reserves for any of its uranium projects. While in the exploration stage, the Company expenses most amounts that would normally be capitalized and subsequently depreciated or depleted over the life of the mining operation on properties that have proven or probable reserves. Items such as the construction of wellfields and related header houses, additions to recovery facilities and advancement of properties are expensed in the period incurred. As a result, the Company’s consolidated financial statements may not be directly comparable to the financial statements of mining companies in the development or production stages. The White Mesa Mill, and certain conventional mining projects in the vicinity of the White Mesa Mill, and the Nichols Ranch Project (collectively the “Extracting and Recovery Operations”) were acquired in two unrelated business combinations. These Extracting and Recovery Operations were recorded at fair value on the date of the respective acquisition and included estimated values which included valuing these assets utilizing the Company’s estimate of future market prices of uranium and expected recoveries of uranium. The values determined included estimated cash flows associated with value beyond proven and probable reserves to develop, extract and recover the estimated saleable uranium concentrates from these operations. The fair value of the Extracting and Recovery Operations recorded on the acquisition date is depreciated on a straight line basis over the estimated useful life of the components of the operation since the Extracting and Recovery Operations do not have proven or probable reserves. Accordingly, all expenditures incurred subsequent to the acquisition dates relating to the preparation of properties for mineral extraction, expansion of or additions to the Extracting and Recovery Operations are expensed as incurred. This includes expenditures relating to activities such as preparing properties for mineral extraction, construction of mine wellfields, header houses and disposal wells and additions to the recovery facilities are expensed as incurred as no proven or probable reserves have been established for these uranium projects. Business combinations Business combinations are accounted for using the acquisition method whereby acquired assets and liabilities are recorded at fair value as of the date of acquisition with any excess of the purchase consideration over such fair value being recorded as goodwill. If the fair value of the net assets acquired exceeds the purchase consideration, the difference is recognized immediately as a gain in the consolidated statement of operations. Mining assets, which include mineral properties and rights, operating mines and recovery facilities, are recorded at fair value and includes estimated values of the mining assets beyond proven and probable reserves as well as the Company’s estimate of future market prices of uranium. The estimated cash flow used to value the mining assets for operating properties and recovery facilities include the estimated cash outflows required to develop, extract and recover the value beyond proven and probable reserves. Non-controlling interest in an acquisition may be measured at either fair value or at the non-controlling interest’s proportionate share of the fair value of the acquiree’s net identifiable assets. The acquisition date is the date the Company acquires control over the acquiree. The Company considers all relevant facts and circumstances in determining the acquisition date. Acquisition related costs, other than costs to issue debt or equity securities of the acquirer, including investment banking fees, legal fees, accounting fees, change in control payments, valuation fees and other professional or consulting fees are expensed as incurred. Impairment of assets The Company reviews and evaluates its long-lived assets for impairment when events or changes in circumstances indicate that the related carrying amounts may not be recoverable. Mineral properties are monitored for impairment based on factors such as mineral prices, government regulation and taxation, the Company's continued right to explore the area, exploration reports, assays, technical reports, drill results and its continued plans to fund exploration programs on the property. At each reporting date, the Company reviews its assets to determine whether there is any indication of impairment. If any such indication exists, the asset is tested for impairment. Impairment losses are recognized in profit or loss. Recoverability is measured by comparing the undiscounted future net cash flows to the net book value. When the net book value exceeds future net undiscounted cash flows, the fair value is compared to the net book value and an impairment loss may be measured and recorded based on the excess of the net book value over fair value. Fair value for operating mines is determined using a combined approach, which uses a discounted cash flow model for the existing operations and non-operating properties 143 with available cash flow models and a market approach for the fair value assessment of non-operating and exploration properties where no cash flow model is available. Future cash flows are estimated based on quantities of recoverable mineralized material, expected uranium prices (considering current and historical prices, trends and estimates), production levels, operating costs, capital requirements and reclamation costs, all based on life-of-mine plans. In estimating future cash flows, assets are grouped at the lowest level, for which there are identifiable cash flows that are largely independent of future cash flows from other asset groups. The Company's estimates of future cash flows are based on numerous assumptions and it is possible that actual future cash flows will be significantly different than the estimates, as actual future quantities of recoverable minerals, uranium prices, production levels, costs and capital are each subject to significant risks and uncertainties. Cash and cash equivalents Cash and cash equivalents consist of all cash balances and highly liquid investments with an original maturity of three months or less. Because of the short maturity of these investments, the carrying amounts approximate their fair value. Restricted cash is excluded from cash and cash equivalents and is included in other current or long-term assets, depending on the nature of the restriction. Investments The Company accounts for investments over which the Company exerts significant influence, but not control, over the financial and operating policies through the fair value option of ASC Topic 825 – Financial Instruments. The cost of such investments is measured at the fair value of the assets given up, shares issued or liabilities assumed at the date of acquisition plus costs directly attributable to the acquisition. Subsequent to initial recognition, they are measured at fair value and changes therein, are recognized in earnings. Unrealized gains and losses on transactions between the Company and its associates are eliminated to the extent of the Company’s interest in its associates. Inventories Expenditures related to the extraction and recovery of uranium concentrates and depreciation of the acquisition cost of the Extracting and Recovery Operations are inventoried as stockpiles and in-process and concentrate inventories. Stockpiles are comprised of uranium bearing materials that have been extracted from properties and are available for further processing. Extraction costs are added to the stockpile as incurred and removed from the stockpile based upon the average cost per ton of material extracted. The current portion of material in stockpiles represents the amount expected to be processed in the next twelve months. In-process and concentrate inventories include the cost of the material processed from the stockpile, as well as production costs incurred to extract uranium bearing fluids from the wellfields, and all costs to recover the uranium into concentrates or process through the White Mesa Mill. Finished uranium concentrate inventories also include costs of any finished product purchased from the market. Recovery costs typically include labor, chemical reagents and directly attributable mill and plant overhead expenditures. Materials and other supplies held for use in the recovery of uranium concentrates are added to the costs of inventories when consumed in the uranium extraction process. Inventories are valued at the lower of average cost or net realizable value. Plant and equipment a. Recognition and measurement Plant and equipment are measured at cost less accumulated depreciation, and any accumulated impairment losses. Cost includes expenditures that are directly attributable to the acquisition of the asset. Subsequent costs are included in the asset’s carrying amount or recognized as a separate asset, when it is replaced, and the cost of the replacement asset is expensed. b. Depreciation and amortization Depreciation and amortization are calculated on a straight line basis to their estimated residual value over an estimated useful life which ranges from 3 to 15 years depending upon the asset type. When assets are retired or sold, the resulting gains or losses are reflected in current earnings as a component of other income or expense. Residual values, method of depreciation and useful lives of the assets are reviewed at least annually and adjusted if appropriate. Where straight-line depreciation is utilized, the range of useful lives for various asset classes is generally as follows: 144 • • • • • • Buildings Shop tools and equipment Mining equipment Office equipment Furniture and fixtures Light trucks & utility vehicles 15 years 3-5 years 5 years 4-5 years 5-7 years 5 years The amortization method, residual values, and useful lives of plant and equipment are reviewed annually, and any change in estimate is applied prospectively. Intangible assets Sales contracts acquired in a business combination are recognized initially at fair value at the acquisition date. The Company’s intangible assets are recorded at cost less accumulated amortization. Amortization is recorded as the Company sells inventory under its long-term sales contracts based on units sold, and is recognized in the statement of operations. Non-operating assets Non-operating assets consist of mineral properties and rights, along with data and analyses related to the properties, which are in various stages of evaluation and permitting. Costs to acquire the non-operating assets are capitalized at cost or fair value if such assets were a part of a business combination. Mining activities for non-operating assets involve the search for minerals, the determination of technical feasibility and the assessment of commercial viability of an identified resource. Expenditures incurred in relation to such mining activities include costs which are directly attributable to researching and analyzing existing exploration data; conducting geological studies, exploratory drilling and sampling; examining and testing extraction and treatment methods; and completing pre-feasibility and feasibility studies. Such expenditures are expensed as incurred. Mineral properties, that are not held for production, and any related surface access to the minerals generally require periodic payments and/or certain expenditures related to the property in order for the Company to retain its interest in the mineral property (collectively, “Holding Costs”). The Company expenses all Holding Costs in the period they are incurred. Stand-by properties Stand-by properties are mineral properties that have extracted mineral resources in the past but are currently non-operating or properties which could extract mineral resources in the future. Expenditures related to these properties are primarily related to maintaining the assets and permits in a condition that will allow re-start of the operations or development given appropriate commodity prices. All costs related to stand-by assets are expensed as incurred. The White Mesa Mill operates on a campaign basis. When the White Mesa Mill is not recovering material, all related costs are expensed as incurred. Asset retirement obligations The Company’s asset retirement obligation (“ARO”) relates to expected mine, wellfield, plant and mill reclamation and closure activities, as well as costs associated with reclamation of exploration drilling. The Company’s activities are subject to numerous governmental laws and regulations. Estimates of future reclamation liabilities for ARO are recognized in the period when such liabilities are incurred. These estimates are updated on a periodic basis and are subject to changing laws, regulatory requirements, changing technology and other factors which will be recognized when appropriate. Liabilities related to site restoration include long-term treatment and monitoring costs and incorporate total expected costs net of recoveries. Expenditures incurred to dismantle facilities, restore and monitor closed resource properties are charged against the related AROs. As the Company has no proven or probable reserves, such costs, discounted to their present value, are expensed as soon as the obligation to incur such costs arises. The present value of AROs is measured by discounting the expected cash flows using a discount factor that reflects the credit-adjusted risk free rate of interest, while taking into account an inflation rate. The decommissioning liability is accreted to full value over time through periodic accretion charges recorded to operations as accretion expense. The Company adjusts the estimate of the ARO for changes in the amount or timing of underlying future cash outflows. The impact of these adjustments to the ARO amounts are expensed as incurred. 145 Loans and borrowings The Company's convertible debentures are recognized at fair value through the fair value option based on the closing price on the TSX and changes are recognized in earnings. The Company’s interest-bearing loans and borrowings are measured at amortized cost using the effective interest method. Warrant liabilities The Company issued several tranches of warrants for various equity transactions in 2016. The Company accounts for its warrants issued in accordance with the U.S. GAAP accounting guidance under FASB ASC Topic 815 Derivative and Hedging ("ASC 815") which requires instruments within its scope to be recorded on the balance sheet as either an asset or liability measured at its fair value, with changes in fair value recognized in earnings. In accordance with ASC 815, the Company has classified the warrants as liabilities. The warrants are subject to re-measurement at each balance sheet date, with any change in fair value recognized as a component of other income (expense), net in the statements of operations. The Company estimates the fair value of these warrants using market prices, if available or the Black-Scholes option pricing model. The Black-Scholes option pricing model is based on the estimated market value of the underlying common stock at the measurement date, the remaining contractual term of the warrant, risk-free interest rates and expected dividends on, and expected volatility of the price of the underlying common stock. Revenue a. Sale of goods Revenue from the sale of mineral concentrates is recognized when it is probable that the economic benefits will flow to the Company and delivery has occurred, title has transferred, the sales price and costs incurred with respect to the transaction can be measured reliably, and collectability is reasonably assured. For uranium concentrates, revenue is typically recognized when delivery is evidenced by book transfer at the applicable uranium storage facility. For vanadium related products, revenue is recognized at the time of shipment, which is when title is transferred to the customer. b. Rendering of services Revenue from toll milling services is recognized as material is processed in accordance with the specifics of the applicable toll milling agreement. Revenue and unbilled accounts receivable are recorded as related costs are incurred using billing formulas included in the applicable toll milling agreement. Revenue from alternate feed process milling is recognized as material is processed, in accordance with the specifics of the applicable processing agreement. Deferred revenues represent proceeds received on delivery of alternate feed materials but in advance of the required processing activity. The Company does not have any obligation to process this material in 2018. Share-based compensation The Company records share based compensation awards exchanged for employee services at fair value on the date of the grant and expenses the awards in the consolidated statement of operations over the requisite employee service period in capital stock. The fair value of stock options is determined using the Black-Scholes valuation model. The fair value of restricted stock units (“RSUs”) is based on the Energy Fuels' stock price on the date of grant. Stock based compensation expense related to awards with only service conditions has a graded vesting schedule which are recorded on a straight-line basis over the requisite service period for each separately vesting portion of the award as if the award was, in substance, multiple awards, while all other awards are recognized on a straight-line basis. The Company's estimates may be impacted by certain variables including, but not limited to, stock price volatility, employee stock option exercise behaviors, additional stock option grants, estimates of forfeitures, the Company's performance, and related tax impacts. Foreign currency Transactions in foreign currencies are translated to the respective functional currency of the Company’s subsidiaries and joint ventures at exchange rates at the dates of the transactions. Monetary assets and liabilities denominated in foreign currencies are translated to the functional currency at the exchange rate as of the reporting date. Non-monetary assets and liabilities that are measured at fair value in a foreign currency are translated to the functional currency at the exchange rate when the fair value was determined. Foreign currency differences are generally recognized in profit or loss. Non-monetary items that are measured based on historical cost in a foreign currency are not translated. The assets and liabilities of entities whose functional currency is not the U.S. dollar are translated into the U.S. dollar at the exchange rate as of the reporting date. The income and expenses of such entities are translated into the U.S. dollar using average exchange rates for the reporting period. Exchange differences on foreign currency translations are recorded in other comprehensive income (loss). The Company’s functional currency is the U.S. dollar. 146 Income taxes The Company uses the asset and liability method of accounting for income taxes. Under this method, deferred income tax assets and liabilities are recorded based on differences between the financial statement carrying values of existing assets and liabilities and their respective income tax bases (temporary differences), and losses carried forward. Deferred income tax assets and liabilities are measured using the enacted tax rates which will be in effect when the temporary differences are likely to reverse. The effect on deferred income tax assets and liabilities of a change in tax rates is included in operations in the period in which the change is enacted. The Company records a valuation allowance to reduce deferred income tax assets to the amount that is believed more likely than not to be realized. When the Company concludes that all or part of the deferred income tax assets are not realizable in the future, the Company makes an adjustment to the valuation allowance that is charged to income tax expense in the period such determination is made. Net loss per share The Company presents basic and diluted loss per share data for its common shares, calculated by dividing the loss attributable to common shareholders of the Company by the weighted average number of common shares outstanding during the period. Diluted loss per share is determined by adjusting the loss attributable to common shareholders and the weighted average number of common shares outstanding for the effects of all potential dilutive instruments. Fair value of financial instruments Fair value accounting utilizes a fair value hierarchy that prioritizes the inputs to valuation techniques used to measure fair value. The hierarchy gives the highest priority to unadjusted quoted prices in active markets for identical assets and liabilities (Level 1 measurements) and the lowest priority to unobservable inputs (Level 3 measurements). The three levels of the fair value hierarchy are described below: Level 1 - Unadjusted quoted prices in active markets that are accessible at the measurement date for identical, unrestricted assets or liabilities Level 2 - Quoted prices in markets that are not active, or inputs that are observable, either directly or indirectly, for substantially the full term of the asset or liability; and Level 3 - Prices or valuation techniques that require inputs that are both significant to the fair value measurement and unobservable (supported by little or no market activity). Our financial instruments include cash and cash equivalents, restricted cash, accounts receivable, accounts payable and current accrued liabilities. These instruments are carried at cost, which approximates fair value due to the short-term maturities of the instruments. Allowances for doubtful accounts are recorded against the accounts receivable balance to estimate net realizable value. The fair value of the Company's debentures are measured at fair value based on the closing price on the TSX (a Level 1 measurement) and changes are recognized in earnings Recently Issued Accounting Pronouncements not yet adopted The FASB has issued the following standards which are not yet effective: Investments In January 2016, ASU No. 2016-01 was issued related to financial instruments. The new guidance requires entities to measure equity investments that do not result in consolidation and are not accounted for under the equity method at fair value and recognize any changes in fair value in net income. This new guidance also updates certain disclosure requirements for these investments. This update is effective in fiscal years, including interim periods, beginning after December 15, 2017, and early adoption is not permitted. The Company is currently evaluating this guidance and the impact it will have on the financial statements. Leases In February 2016, the FASB issued ASU 2016-02 which core principle is that a lessee should recognize the assets and the liabilities that arise from leases, including operating leases. Under the new requirements, a lessee will recognize in the balance sheet a liability to make lease payments (the lease liability) and the right-of-use asset representing the right to the underlying asset for the lease term. For leases with a term of twelve months or less, the lessee is permitted to make an accounting policy election by class of underlying asset not to recognize lease assets and lease liabilities. The recognition, measurement, and presentation of expenses and cash flows arising from a lease by a lessee have not significantly changed from the previous GAAP. The standard is effective for fiscal years beginning after December 15, 2018, including interim periods within such fiscal year, with early adoption permitted. 147 The ASU requires a modified retrospective transition method with the option to elect a package of practical expedients. The Company is evaluating the effect of this amendment and the impact it will have on the Company’s financial statements. Revenue recognition In May 2014, the FASB issued ASU No. 2014-09, as amended by ASU No. 2016-12, "Revenue from Contracts with Customers (Topic 606)," which requires revenue to be recognized based on the amount an entity is expected to be entitled to for promised goods or services provided to customers. The standard also requires expanded disclosures regarding contracts with customers. The guidance in this standard supersedes the revenue recognition requirements in Topic 605, "Revenue Recognition," and most industry-specific guidance. Adoption of the standard may be applied retrospectively to each prior period presented (full retrospective method) or retrospectively with the cumulative effect recognized as of the date of initial application (modified retrospective method). This guidance is effective for us beginning January 1, 2018 and we will apply the modified retrospective method. Accordingly, for our public filings beginning with our Quarterly Report on Form 10-Q for the quarter ending March 31, 2018, we will present prior periods as if revenue were recognized under Topic 606. Our revenue is primarily generated from the sale of uranium to customers. These sales predominantly contain a single delivery element and revenue is recognized at a single point in time when ownership, risk and rewards transfer to the buyer. The Company is finalizing the analysis of the effects of ASU 2014-09 on the consolidated financial statements, and subject to completion of this analysis, the Company expects to record a cumulative effect of adoption adjustment as of January 1, 2018 to decrease accumulated deficit earnings by approximately $2.50 million, reflecting the gross profit the Company would have recognized under ASU 2014-09 if applied as of December 31, 2017. In addition to accelerating the timing of recording revenue, the Company expects a corresponding decrease in deferred revenue. The Company is in the process of implementing and refining the required changes to its business and accounting processes, and internal controls to support recognition and disclosures under the new standard. 4. ACQUISITION OF THE ALTA MESA ISR PROJECT On June 16, 2016, the Company acquired 100% of the membership interests of EFR Alta Mesa LLC (“Alta Mesa”) (formerly named “Mesteña Uranium, LLC”) and its related companies, together referred to as “Alta Mesa”. Under the terms of the acquisition agreement, the sellers of Alta Mesa received 4,551,284 common shares of the Company. Alta Mesa’s primary asset is the Alta Mesa ISR Project (the “Alta Mesa Project”) located in Texas. The Alta Mesa Project is a fully-permitted and licensed production facility that is not currently operating. The acquisition was accounted for as a purchase of assets as Alta Mesa did not meet the definition of a business under ASC Topic 805, Business Combinations because the assets in Alta Mesa do not have developed wellfields which are a key process for extraction of uranium. The development can only commence once uranium prices improve and economic feasibility of the Alta Mesa Project is established. The measurement of the purchase consideration was based on the market price of the Company's common stock on June 16, 2016 of $2.50 per share. The total transaction costs incurred through June 30, 2016 by the Company were $1.29 million which were capitalized as part of the purchase consideration. The aggregate fair values of assets acquired and liabilities assumed were as follows on the acquisition date: Issuance of 4,551,824 common shares Transaction costs Purchase consideration The purchase price was allocated as follows: Plant and equipment (a) Inventories Restricted cash Accounts payable and accrued liabilities Asset retirement obligation Net identifiable assets $ $ $ 11,378 1,290 12,668 13,626 177 4,532 (213) (5,454) $ 12,668 (a) The plant and equipment includes the value ascribed to the processing plant and equipment. The mineral properties, which were acquired as part of the acquisition of Alta Mesa in 2016, do not have proven and probable reserves under SEC 148 Industry Guide 7. Accordingly, all subsequent expenditures at the Alta Mesa Project and equipment, which do not have any alternative use, and expenditures on mineral properties will be expensed as incurred. 5. ACQUISITION OF URANERZ ENERGY CORPORATION On June 18, 2015, the Company acquired 100% of the outstanding shares of Uranerz Energy Corporation. Under the terms of the acquisition agreement, shareholders of Uranerz received 0.255 common shares of the Company for each share of Uranerz common stock held. Each outstanding Uranerz option or warrant was converted into an option or warrant (as applicable) to acquire common shares of the Company, on the same terms and conditions as were applicable to the stock option or warrant (as applicable) prior to the acquisition, except that the number of shares subject to the option or warrant and the exercise price of the option or warrant were adjusted based on the exchange ratio of 0.255, so as to preserve the economic value of such options or warrants. Uranerz, now a wholly owned subsidiary of the Company, is a United States-based uranium company focused on in-situ uranium recovery. ISR is a uranium extraction process that uses a “leaching solution” to extract uranium from underground sandstone- hosted uranium resources and then recover the uranium in the form of uranium concentrates. Uranerz controls a land position in the central Powder River Basin in Wyoming, where it operates the Nichols Ranch Project. The acquisition of Uranerz provided the Company with ISR capabilities and the capability to expand ISR extraction and recovery in the future. The acquisition was accounted for using the acquisition method in accordance with ASC Topic 805, Business Combinations, with the Company being identified as the acquirer. The measurement of the purchase consideration was based on the market price of the Company's common stock on June 18, 2015 which was $4.16 per share. The total purchase price, including the fair value of the options and warrants, amounted to $106.34 million. The total transaction costs incurred through December 31, 2015 by the Company were $6.89 million which were recorded in Costs directly attributable to acquisitions and are comprised of cash costs of $2.96 million and the issuance of 889,436 common shares of the Company for a total value of $3.93 million for advisory fees and to settle a portion of required change in control payments to certain employees of Uranerz. The final allocation of the purchase price, based on the fair value of assets acquired and liabilities assumed on June 18, 2015, is summarized in the following table: Purchase price Issuance of 24,457,773 common shares for replacement of Uranerz common shares Issuance of 2,690,250 warrants for replacement of Uranerz warrants (Note 12) Issuance of 2,040,408 options for replacement of Uranerz share based options (Note 12) Uranerz purchase price allocation Cash and cash equivalents Inventories Prepaid expenses and other assets Plant and equipment Mineral properties Intangible assets - customer contracts Restricted cash Accounts payable and accrued liabilities Loans and borrowings Asset retirement obligation Non-controlling interest Goodwill Total purchase consideration $ $ $ 101,744 915 3,681 106,340 2,459 3,742 402 29,974 36,563 10,600 2,100 (2,280) (18,813) (2,145) (3,992) 47,730 $ 106,340 The purchase consideration was allocated to the fair value of assets acquired and liabilities assumed, based on an independent valuation report and management's best estimates. 149 6. RECEIVABLES Current Trade receivables - other Notes receivable, net Non-current Notes receivable and other December 31, 2017 December 31, 2016 $ $ $ $ 403 850 $ 1,253 $ $ 903 903 $ 364 — 364 1,146 1,146 During the year ended December 31, 2014 the Company received two notes with the principal totaling $1.05 million due in 2018 in connection with the sale of certain assets previously recorded as held for sale. These notes carry a 3% annual interest payment. The Company has setup a reserve of $0.22 million as of December 31, 2017 (2016 - $0.22 million) against the collectability of these receivables. 7. INVENTORIES Concentrates and work-in-progress (a) Raw materials and consumables December 31, 2017 December 31, 2016 $ $ 14,118 $ 2,432 16,550 $ 13,788 2,973 16,761 (a) For the year ended December 31, 2017, the Company recorded an impairment loss of $3.31 million in the statement of operations related to concentrates and work in progress inventories (December 31, 2016 - $5.36 million). 8. INTANGIBLE ASSETS The following is a summary of changes in intangible assets related to favorable sales contracts acquired in business combinations for the years ended December 31, 2017 and December 31, 2016: Sales Contracts Cost Balance at beginning of period Sales contracts fulfilled Balance, end of period Accumulated amortization, beginning of period Amortization of sales contracts Sales contracts fulfilled Accumulated amortization, end of period Net book value December 31, 2017 December 31, 2016 $ 15,034 $ (4,435) 10,599 9,235 3,297 (4,435) $ 8,097 2,502 $ 18,657 (3,623) 15,034 9,540 3,318 (3,623) 9,235 5,799 The sales contracts when acquired were recorded at their acquisition date fair value, which are the incremental cash flows available to the Company arising from above-market pricing of the contracts. Amortization expense for 2018 will be $2.50 million. 150 9. PLANT AND EQUIPMENT AND MINERAL PROPERTIES The following is a summary of plant and equipment: December 31, 2017 December 31, 2016 Cost Accumulated Depreciation Net Book Value Cost Accumulated Depreciation Net Book Value Plant and equipment Nichols Ranch $ 29,210 $ (9,971) $ 19,239 $ 29,210 $ (6,804) $ 22,406 Alta Mesa Equipment and other Plant and equipment total 13,626 13,367 (1,388) (11,768) 12,238 1,599 13,626 13,367 (456) (11,361) 13,170 2,006 $ 56,203 $ (23,127) $ 33,076 $ 56,203 $ (18,621) $ 37,582 The net book value for Nichols Ranch Project includes the value beyond proven and probable reserves ascribed to the processing plant, the Nichols Ranch wellfields and the Jane Dough project upon acquisition. For the year ended December 31, 2017, the Company recorded $3.17 million (2016 - $4.43 million) of depreciation expense related to Nichols Ranch, which is included in the costs and expenses applicable to revenue in the Statement of the operations and comprehensive income for the year ended December 31, 2017. The following is a summary of mineral properties: Mineral properties Uranerz ISR properties (a) Sheep Mountain Roca Honda (b) Other (a) Mineral properties total December 31, 2017 December 31, 2016 $ $ 25,974 $ 34,183 22,095 1,287 83,539 $ 35,060 34,183 22,095 1,287 92,625 a) b) In the year ended December 31, 2017 the Company did not renew certain mineral leases and recorded abandonment expense of $0.29 million (December 31, 2016 – $1.04 million, December 31, 2015 – $2.77 million) in the statement of operations. On May 27, 2016, the Company issued 1,212,173 shares to acquire the remaining 40% interest of the Roca Honda project for consideration of $2.63 million and an additional $4.5 million in cash payable upon first commencement of commercial mineral extraction. The acquisition was accounted for as a purchase of assets as Roca Honda does not meet the definition of a business under FASB ASC Topic 805, Business Combinations because Roca Honda does not currently have the resources, both inputs and processes, to apply to the Roca Honda property in order to extract uranium. 10. IMPAIRMENTS Impairment of goodwill In the year ended December 31, 2015, the Company recorded goodwill of $47.73 million associated with the acquisition of Uranerz on June 18, 2015. The goodwill represents the excess of the acquisition date fair value of the purchase consideration, over the fair value of the assets acquired, net of obligations assumed, and is ascribed to the ISR reporting unit. In the period following the acquisition of Uranerz to December 31, 2015, uranium spot market prices had fallen approximately 20% and the value of the Company’s shares and related market capitalization had decreased significantly. As a result, during the Company’s annual impairment test for goodwill performed as of December 31, 2015 the Company evaluated the carrying amount of the goodwill and determined that the goodwill should be fully impaired at December 31, 2015 (refer to note 21 for disclosure of the Company’s valuation methodology). 151 Impairment of plant and equipment, mineral properties and mineral properties held for sale The Company conducts a review of potential triggering events for all its mineral properties on a quarterly basis. When events or changes in circumstances indicate that the related carrying amounts may not be recoverable, the Company carries out a review and evaluation of its long-lived assets in accordance with its accounting policy. No such events or changes in circumstances were noted in the year ended December 31, 2017. In the year ended December 31, 2017 the Company entered into an agreement to sell certain non-core uranium properties. The Company reclassifed these properties as held for sale and recorded an impairment of $3.80 million. The impaired properties are in the Reno Creek area. The impairment was based of the estimate of its fair value determined using the market approach less estimated selling costs. In the year ended December 31, 2015, the Company identified indicators of impairment of its mineral properties due to the decline in the uranium concentrate spot and long-term prices and deterioration in the Company’s expectation of future uranium concentrate prices with respect to the Company's mineral properties. An impairment analysis was performed for these properties using the assumptions listed in note 21. The Company compared the undiscounted cash flows for the mineral properties tested with their carrying amounts. No impairment was considered necessary with respect of Roca Honda, Sheep Mountain properties and the ISR mineral properties, since the undiscounted cash flows exceeded the carrying amounts for the properties. With respect of mineral properties identified as held for sale the Company recorded an impairment totaling $8.22 million. The impaired properties included Copper King, Marquez Ranch, Gas Hills, Juniper Ridge and the Nose Rock. These properties are classified in the other category of the conventional segment. The impairment was based of the estimate of its fair value determined using the market approach less estimated selling costs. In 2016, the Copper King, Marquez Ranch and Nose Rock mineral interests with a carrying amount of $1.30 million were sold in separate transactions for gross proceeds totaling $1.36 million. 11. ASSET RETIREMENT OBLIGATIONS AND RESTRICTED CASH The following table summarizes the Company’s asset retirement obligations: Asset retirement obligation, beginning of period Revision of estimate Acquired in asset acquisitions or business combinations Accretion of liabilities Settlements Asset retirement obligation, end of period Asset retirement obligation: Current Non-current Asset retirement obligation, end of period December 31, 2017 December 31, 2016 $ $ $ $ 17,033 $ 249 — 1,733 (735) 18,280 $ $ 32 18,248 18,280 $ 8,573 4,186 5,454 906 (2,086) 17,033 32 17,001 17,033 The asset retirement obligations of the Company are subject to legal and regulatory requirements. Estimates of the costs of reclamation are reviewed periodically by the Company and the applicable regulatory authorities. The above provision represents the Company’s best estimate of the present value of future reclamation costs, discounted using credit adjusted risk-free interest rates ranging from 9.5% to 11.5% and an inflation rate of 2.0%. The total undiscounted decommissioning liability at December 31, 2017 is $43.46 million. The following table summarizes the Company’s restricted cash: Restricted cash, beginning of period Restricted cash from acquisitions Refunds of collateral Additional collateral posted Restricted cash, end of period December 31, 2017 December 31, 2016 $ $ 23,175 $ — (14,657) 13,609 22,127 $ 12,980 4,532 — 5,663 23,175 152 The Company has cash, cash equivalents and fixed income securities as collateral for various bonds posted in favor of the applicable state regulatory agencies in Arizona, Colorado, New Mexico, Texas, Utah and Wyoming, and the U.S. Bureau of Land Management and U.S. Forest Service for estimated reclamation costs associated with the White Mesa Mill, Nichols Ranch, Alta Mesa and other mining properties. Cash equivalents are short-term highly liquid investments with original maturities of three months or less. The restricted cash will be released when the Company has reclaimed a mineral property or restructured the surety and collateral arrangements. See Note 18 for a discussion of the Company’s surety bond commitments. 12. LOANS AND BORROWINGS The contractual terms of the Company’s interest-bearing loans and borrowings, which are recorded at amortized cost, and the Company’s convertible debentures which are recorded at fair value, are as follows. Current portion of loans and borrowings: Convertible debentures (a) Wyoming Industrial Development Revenue Bond loan (b) Total current loans and borrowings Long-term loans and borrowings: Convertible debentures (a) Wyoming Industrial Development Revenue Bond loan (b) Total long-term loans and borrowings Terms and debt repayment schedule Terms and conditions of outstanding loans were as follows: December 31, 2017 December 31, 2016 $ $ $ $ — $ 3,414 3,414 $ 16,636 $ 7,441 24,077 $ 3,095 3,224 6,319 12,381 10,854 23,235 Convertible debentures (a) CDN$ 8.5% 2020 $16,636 $16,636 $16,385 Currency Nominal interest rate Year of maturity Face value Carrying amount Face value Carrying amount $15,476 December 31, 2017 December 31, 2016 Wyoming Industrial Development Revenue Bond loan (b) USD 5.8% 2020 10,855 $27,491 10,855 $27,491 14,078 $30,463 14,078 $29,554 On July 24, 2012, the Company completed a bought deal public offering of 22,000 floating-rate convertible (a) unsecured subordinated debentures originally maturing June 30, 2017 (the “Debentures”) at a price of Cdn$1,000 per Debenture for gross proceeds of Cdn$21.55 million (the “Offering”). The Debentures are convertible into common shares at the option of the holder. Interest is paid in cash and in addition, unless an event of default has occurred and is continuing, the Company may elect, from time to time, subject to applicable regulatory approval, to satisfy its obligation to pay interest on the Debentures, on the date it is payable under the indenture: (i) in cash; (ii) by delivering sufficient common shares to the debenture trustee, for sale, to satisfy the interest obligations in accordance with the indenture in which event holders of the Debentures will be entitled to receive a cash payment equal to the proceeds of the sale of such common shares; or (iii) any combination of (i) and (ii). On August 4, 2016, the Company, by a vote of the Debentureholders, extended the maturity date of the Debentures from June 30, 2017 to December 31, 2020, and reduced the conversion price of the Debentures from Cdn$15.00 to Cdn$4.15 per common share of the Company. In addition, a redemption provision was added that enables the Company, upon giving not less than 30 days' notice to Debentureholders, to redeem the Debentures, for cash, in whole or in part at any time after June 30, 2019, but prior to maturity, at a price of 101% of the aggregate principal amount redeemed, plus accrued and unpaid interest (less any tax required by law to be deducted) on such Debentures up to but excluding the redemption date. A right (in favor of each Debentureholder) was also added to give the Debentureholders the option to require the Company to purchase, for cash, on the previous maturity date of June 30, 2017, up to 20% of the Debentures held by the 153 Debentureholders at a price equal to 100% of the principal amount purchased plus accrued and unpaid interest (less any tax required by law to be deducted). The Debentures accrue interest, payable semi-annually in arrears on June 30 and December 31 of each year at a fluctuating rate of not less than 8.5% and not more than 13.5%, indexed to the simple average spot price of uranium as reported on the UxC Weekly Indicator Price. The Debentures may be redeemed in whole or part, at par plus accrued interest and unpaid interest by the Company between June 30, 2019 and December 31, 2020 subject to certain terms and conditions, provided the volume weighted average trading price of the common shares of the Company on the TSX during the 20 consecutive trading days ending five days preceding the date on which the notice of redemption is given is not less than 125% of the conversion price. Upon redemption or at maturity, the Company will repay the indebtedness represented by the Debentures by paying to the debenture trustee in Canadian dollars an amount equal to the aggregate principal amount of the outstanding Debentures which are to be redeemed or which have matured, as applicable, together with accrued and unpaid interest thereon. Subject to any required regulatory approval and provided no event of default has occurred and is continuing, the Company has the option to satisfy its obligation to repay the Cdn$1,000 principal amount of the Debentures, in whole or in part, due at redemption or maturity, upon at least 40 days’ and not more than 60 days’ prior notice, by delivering that number of common shares obtained by dividing the Cdn$1,000 principal amount of the Debentures maturing or to be redeemed as applicable, by 95% of the volume-weighted average trading price of the common shares on the TSX during the 20 consecutive trading days ending five trading days preceding the date fixed for redemption or the maturity date, as the case may be. In accordance with the revised terms approved on August 4, 2016, the Company had classified 20% of the principal amount of the Debenture as a current liability at December 31, 2016. Upon expiration of the option at June 30, 2017, the Company reclassified the amount not redeemed as a long term liability. The Debentures are classified as fair value through profit or loss where the Debentures are measured at fair value based on the closing price on the TSX (a Level 1 measurement) and changes are recognized in earnings. For the year ended December 31, 2017 the Company recorded a loss on revaluation of convertible debentures of $0.94 million (December 31, 2016 – $0.41 million). The Company, upon its acquisition of Uranerz, assumed a loan through the Wyoming Industrial Development (b) Revenue Bond program (the "Loan"). The Loan has an annual interest rate of 5.75% and is repayable over seven years, maturing on October 15, 2020. The Loan originated on December 3, 2013 and required the payment of interest only for the first year, with the amortization of principal plus interest over the remaining six years. The Loan can be repaid earlier than its maturity date if the Company so chooses without penalty or premium. The Loan is secured by most of the assets of the Company’s wholly owned subsidiary, Uranerz, including mineral properties, the processing facility, and equipment as well as an assignment of all of Uranerz’rights, title and interest in and to its product sales contracts and other agreements. Uranerz is also subject to dividend restrictions. Principal and interest are paid on a quarterly basis on the first day of January, April, July and October. At December 31, 2017 the loan had an outstanding balance of $10.86 million of which the current portion of the loan was $3.41 million. 13. CAPITAL STOCK Authorized capital stock The Company is authorized to issue an unlimited number of common shares without par value, unlimited preferred shares issuable in series, and unlimited Series A preferred shares. The Series A preferred shares are non-redeemable, non-callable, non-voting and with no right to dividends. The Preferred Shares issuable in series will have the rights, privileges, restrictions and conditions assigned to the particular series upon the Board of Directors approving their issuance. Issued capital stock The significant transactions relating to capital stock issued during 2017, 2016, and 2015 are: a) b) In the year ended December 31, 2017, the Company issued 7,202,479 common shares under the Company’s “at-the- market” offering (the “ATM”) for proceeds of $14.55 million. In the year ended December 31, 2016, the Company issued 200,225 common shares under the Company’s ATM for proceeds of $0.54 million. In the year ended December 31, 2015 the Company issued 1,275,908 shares under the Company’s ATM for proceeds of $2.94 million. On March 14, 2016, the Company completed a public offering of 5,031,250 units at a price of $2.40 per unit for gross proceeds of $12.08 million. Each Unit consisted of one common share and one half of one common share purchase warrant, or a total of 5,031,250 common shares and 2,515,625 warrants. Each warrant is exercisable until March 14, 2019 and entitles the holder thereof to acquire one common share upon exercise at an exercise price of US$3.20 per common 154 share. These warrants are accounted for as a derivative liability, as the functional currency of the entity issuing the warrant is Cdn$. The following weighted average assumptions were used for the Black-Scholes option pricing model to calculate the $2.09 million of fair value for the 2,515,625 warrants issued in connection with the public offering in March 2016. Risk-free rate Expected life Expected volatility Expected dividend yield 1.15% 3.0 years 106.0%* 0% * Expected volatility is measured based on the Company’s historical share price volatility over the expected life of the warrants. c) d) e) On May 27, 2016, the Company issued 1,212,173 shares to acquire the remaining 40% interest of the Roca Honda Joint Venture for share consideration of $2.68 million. On June 16, 2016 the Company issued 4,551,284 shares to acquire Alta Mesa with a value of $11.38 million. On September 20, 2016, the Company completed a public offering of 8,337,500 units at a price of $1.80 per unit for gross proceeds of $15.01 million. Each Unit consisted of one common share and one half of one common share purchase warrant, or a total of 8,337,500 Shares and 4,168,750 Warrants. Each warrant is exercisable until September 20, 2021 and entitles the holder thereof to acquire one common share upon exercise at an exercise price of US$2.45 per common share. These warrants are accounted for as a derivative liability, as the functional currency of the entity issuing the warrant is Cdn$. The following weighted average assumptions were used for the Black-Scholes option pricing model to calculate the $3.17 million of fair value for the 4,168,750 warrants issued in connection with the public offering in September 2016. Risk-free rate Expected life Expected volatility Expected dividend yield 1.2% 5.0 years 145.2%* 0% * Expected volatility is measured based on the Company’s historical share price volatility over the expected life of the warrants. f) On June 18, 2015 the Company issued 24,457,773 shares for the acquisition of Uranerz Energy Corp valued at $101.74 million. Pursuant to the acquisition of Uranerz, the Company issued 617,832 EFI common shares valued at $2.57 million in satisfaction of an advisory fee. The value of the Energy Fuels' shares issued for the advisory fee was calculated using the share price of the Company’s common shares on the date the acquisition closed and these costs were expensed in the consolidated financial statements of the Company. On June 25, 2015 the Company issued 271,604 EFI common shares valued at $1.36 million to former employees of Uranerz in consideration for termination liabilities. The value of the Energy Fuels' shares issued was calculated using the share price of the Company’s shares on the date the shares were issued. These costs were expensed in the consolidated financial statements of the Company. Share Purchase Warrants The following table summarizes the Company’s share purchase warrants denominated in US dollars. These warrants are accounted for as derivative liabilities as the functional currency of the entity issuing the warrants, Energy Fuels Inc., is Canadian dollars. Month Issued March 2016 (1) September 2016 (2) Expiry Date March 14, 2019 September 20, 2021 Exercise Price USD$ Warrants Outstanding Fair value at December 31, 2017 3.20 2.45 2,515,625 $ 4,168,750 $ 385 2,991 3,376 (1) These US dollar based warrants are classified as Level 2 under the fair value hierarchy (Note 13). (2) These US dollar based warrants are classified as Level 1 under the fair value hierarchy as they are traded on an active market. 155 The following weighted average assumptions were used for the Black-Scholes option pricing model to calculate the $0.39 million of fair value for the 2,515,625 warrants at December 31, 2017. Risk-free rate Expected life Expected volatility Expected dividend yield 1.76% 1.2 years 63.7%* 0% * Expected volatility is measured based on the Company’s historical share price volatility over the expected life of the warrants. 14. BASIC AND DILUTED LOSS PER COMMON SHARE The following is a reconciliation of weighted average shares outstanding for the years ended December 31, 2017, 2016, 2015, respectively: Issued common shares at beginning of period Effect of share options exercised Years Ended December 31, 2017 2016 2015 66,205,153 — 46,519,132 3,471 19,677,552 22,938 Effect of shares issued for settlement of vesting of restricted share units 831,393 196,242 Effect of shares issued for exercise of share purchase warrants Effect of shares issued in business combinations Effect of shares issued in asset acquisitions Effect of shares issued in public offerings Weighted average shares outstanding Basic and diluted loss per share — — — 3,822,561 — — 3,184,175 6,538,038 — 173 13,654,488 — 28,821 70,859,107 56,441,058 33,383,972 The calculation of diluted earnings per share after adjustment for the effects of all potential dilutive common shares, calculated as follows: Net loss Basic and diluted weighted average number of common shares outstanding Loss per common share Years Ended December 31, 2017 2016 2015 $ (27,766) $ (39,413) $ (82,217) 70,859,107 56,441,058 33,383,972 $ (0.39) $ (0.70) $ (2.46) For the three years ended December 31, 2017, 2016 and 2015, 8.71 million, 10.19 million and 5.21 million options and warrants, respectively, and the potential conversion of the debentures have been excluded from the calculation as their effect would have been anti-dilutive. 15. SHARE-BASED PAYMENTS The Company, under the 2015 Omnibus Equity Incentive Compensation Plan (the “Compensation Plan”), maintains a stock incentive plan for directors, executives, eligible employees and consultants. Stock incentive awards include employee stock options and restricted stock units (“RSUs”). The Company issues new shares of common stock to satisfy exercises and vesting under all of its stock incentive awards. At December 31, 2017, a total of 7,436,682 common shares were authorized for stock incentive plan awards. Employee Stock Options The Company, under the Compensation Plan may grant options to directors, executives, employees and consultants to purchase common shares of the Company. The exercise price of the options is set as the higher of the Company’s closing share price on the day before the grant date or the five-day volume weighted average price. Stock options granted under the Compensation Plan 156 generally vest over a period of two years or more and are generally exercisable over a period of five years from the grant date not to exceed 10 years. The value of each option award is estimated at the grant date using the Black-Scholes Option Valuation Model. There were 0.74 million options granted in the year ended December 31, 2017 (December 31, 2016 – 0.45 million, December 31, 2015 - 2.17 million). At December 31, 2017, there were 2.03 million options outstanding with 1.66 million options exercisable, at a weighted average exercise price of $4.48 and $4.96 respectively, with a weighted average remaining contractual life of 3.59 years. The aggregate intrinsic value of the fully vested shares was $nil. The summary of the Company’s stock options at December 31, 2017, 2016 and 2015, respectively, and the changes for the fiscal periods ending on those dates are presented below: Balance, January 1, 2015 Granted Exercised Forfeited Expired Balance, December 31, 2015 Granted Exercised Forfeited Expired Balance, December 31, 2016 Granted Exercised Forfeited Expired Balance, December 31, 2017 Range of Exercise Prices $ Weighted Average Exercise Price $ Number of Options 7.60 - 44.22 2.55 - 18.55 2.55 - 4.48 4.44 - 29.71 7.47 - 32.10 2.55 - 32.10 2.12 - 2.22 2.12 2.12 - 18.99 2.95 - 32.03 2.12 - 15.61 1.77 - 2.35 — 2.12 - 11.94 4.48 - 12.55 1.77 - 15.61 11.66 6.02 3.78 7.29 7.42 6.54 2.13 2.12 5.52 8.03 5.69 2.34 — 2.93 8.42 4.48 905,413 2,176,330 (48,802) (574,486) (335,558) 2,122,897 449,537 (8,369) (317,960) (200,962) 2,045,143 738,893 — (316,289) (438,900) 2,028,847 As of December 31, 2017, the outstanding stock options denominated in Cdn$ were as follows: Options outstanding Weighted average remaining contractual life Weighted average price 8.26 1.17 Options exercisable Weighted average remaining contractual life Weighted average price 8.26 1.17 Intrinsic Value — — $ Intrinsic Value Quantity — — 393,100 393,100 $ Exercise price Quantity $5.00 to $9.99 393,100 393,100 As of December 31, 2017, the outstanding stock options denominated in USD$ were as follows: 157 Options outstanding Weighted average price Weighted average remaining contractual life Intrinsic Value Quantity Options exercisable Weighted average price Weighted average remaining contractual life Intrinsic Value Exercise price Quantity $0.00 to $4.99 1,276,456 $ $5.00 to $9.99 $10.00 to $14.99 255,762 90,779 $15.00 to $19.99 12,750 $ 2.97 6.00 10.69 15.61 1,635,747 4.49 4.10 0.50 3.03 $ $ — — — — — 911,276 $ 255,762 90,779 12,750 $ 1,270,567 3.24 6.00 10.69 15.61 4.73 $ 4.10 0.50 3.03 $ — — — — — In the year ended December 31, 2016 the Company issued 8,369 shares upon exercise of stock options at an average exercise price of $2.12 for proceeds of $0.02 million. These options had an intrinsic value of $0.01 million. In the year ended December 31, 2015 the Company issued 48,802 shares upon exercise of stock options at an average exercise price of $3.87 for proceeds of $0.18 million. These options had an intrinsic value of $0.06 million. The share-based compensation recorded during the years ended months ended December 31, 2017, 2016 and 2015 is as follows: Share-based compensation (1)(2) Replacement of options from business combinations and asset acquisitions (3) Value of stock options and RSUs granted Years ended December 31, 2016 2017 2015 $ $ 3,525 $ — 2,657 $ — 1,099 3,681 3,525 $ 2,657 $ 4,780 (1) The fair value of the options granted under the Compensation Plan for the years ended December 31, 2017, 2016 and 2015, was estimated at the date of grant, using the Black-Scholes Option Valuation Model, with the following weighted-average assumptions: Risk-free interest rate Expected life Expected volatility Expected dividend yield Weighted-average expected life of option Weighted-average grant date fair value 2017 2016 2015 1.93% 5.0 years 63.0%* 0% 5.00 $1.20 1.03% - 1.43% 5.0 years 64.7% -74.8%* 0% 5.00 $1.22 - $1.23 0.87% 5.0 years 75.1%* 0% 4.99 2.64 * Expected volatility is measured based on the Company’s historical share price volatility over a period equivalent to the expected life of the options. (2) The fair value of the RSUs granted under the Compensation Plan for the years ended December 31, 2017, 2016 and 2015, was estimated at the date of grant, using the stated market price. (3) For business combinations and asset acquisitions the Company may issue options to replace options of the acquired companies. For the year ended December 31, 2015, the fair value of stock options granted to employees, directors and consultants of companies acquired through business combinations and asset acquisitions was estimated on the closing date of the transaction using the Black-Scholes option pricing model with the following assumptions: 158 Risk-free interest rate Expected life Expected volatility Expected dividend yield Weighted-average expected life of option Weighted-average grant date fair value 0.0% to 2.35% 0.05 years to 10 years 18.47 to 93.31%* 0% 4.52 $1.89 * Expected volatility is measured based on the Company’s historical share price volatility over a period equivalent to the expected life of the options. A summary of the status and activity of non-vested stock options at December 31, 2017 is as follows: Non-vested January 1, 2015 Granted Vested Forfeited Non-vested December 31, 2015 Granted Vested Forfeited Non-vested December 31, 2016 Granted Vested Forfeited Non-vested December 31, 2017 Restricted Stock Units Number of shares Weighted Average Grant- Date Fair Value 139,600 $ 2,176,330 (2,119,803) (18,429) 177,698 449,537 (331,482) (68,575) 227,178 738,893 (486,386) (114,505) 365,180 $ 5.27 1.93 2.00 5.17 3.44 1.29 2.26 1.56 1.48 1.18 1.30 1.22 1.20 The Company grants RSUs to executives and eligible employees. Awards are determined as a target percentage of base salary and vest over periods of three years. Prior to vesting, holders of restricted stock units do not have the right to vote the underlying shares. The restricted stock units are subject to forfeiture risk and other restrictions. Upon vesting, the employee is entitled to receive one share of the Company’s common stock for each restricted stock unit for no additional payment. During the year ended December 31, 2017, the Company’s Board of Directors approved the issuance of 1.39 million RSUs under the Compensation Plan (2016 – 1.21 million, 2015 - 0.28 million). A summary of the status and activity of non-vested RSUs at December 31, 2017 is as follows: 159 Non-vested January 1, 2015 Granted Vested Forfeited Non-vested December 31, 2015 Granted Vested Forfeited Non-vested December 31, 2016 Granted Vested Forfeited Non-vested December 31, 2017 Number of shares Weighted Average Grant- Date Fair Value — $ 282,716 — (9,850) 272,866 1,205,336 (138,608) (9,125) 1,330,469 1,390,705 (752,580) (59,118) 1,909,477 $ — 4.05 — 4.68 4.03 2.14 4.65 5.39 2.37 2.09 2.35 2.29 2.17 The total fair value of RSUs that vested and were settled for equity in the year ended December 31, 2017 was $1.69 million (2016 – $0.30 million, 2015 - $nil). At December 31, 2017, there was $0.11 million and $1.26 million of unrecognized compensation costs related to the unvested stock options and RSU awards, respectively. This cost is expected to be recognized over a period of approximately three years. 16. INCOME TAXES A reconciliation of income tax expense and the product of accounting income before income tax, multiplied by the combined Canadian federal and provincial income tax rate (the rate applicable to the Canadian parent company) is as follows: Loss before income taxes Combined federal and provincial rate Expected income tax recovery Stock based compensation Other non-deductible/non-taxable items Foreign tax rate differences Unrecognized deferred tax assets Income tax expense Year ended December 31, 2016 2015 2017 $ (27,990) $ (39,864) $ (82,357) 26.50% 26.50% (10,600) 704 — (2,962) 12,858 26.50% (21,825) 291 (2,984) (10,180) 34,698 $ — $ — (7,400) 934 (1,303) — 7,769 — $ 160 The components of the net deferred tax assets and liabilities as of December 31, 2017, 2016 and 2015 are as follows: Current deferred tax assets Inventories Short-term investments Total current deferred tax assets Non-current deferred tax assets Operating loss carry forwards Capital loss carry forwards Deferred revenue and other Mineral properties and deferred costs Asset retirement obligations Intangibles and other Property, plant and equipment Total non-current deferred tax assets Subtotal deferred tax asset Less: valuation allowance Net deferred tax asset Year ended December 31, 2017 2016 2,148 1,216 3,364 74,644 15,286 3,695 28,080 4,844 (663) 845 126,731 130,095 2,900 413 3,313 91,441 21,322 3,885 40,581 6,398 (2,524) (751) 160,352 163,665 (130,095) (163,665) $ — $ — At December 31, 2017, and 2016, the Company recorded a valuation allowance against the net deferred tax assets for the above related items in the financial statements as management did not consider it more likely than not that the Company will be able to realize the deferred tax assets in the future. The following table summarizes the changes to the valuation allowance: For the Year Ended December 31, 2017 2016 Balance at Beginning of Period 163,666 153,651 Additions (a) Deductions (b) 4,259 11,166 (37,830) (1,151) Balance at End of Period 130,095 163,666 a) b) The additions to the valuation allowance result from additional losses incurred, increases to other tax assets such as mineral property and property, plant and equipment. Management does not feel these additions meet the more-likely- than-no criterion for recognition. The reductions to the valuation allowance result primarily from the decrease in the net unrecognized deferred tax asset due to the change in the U.S. tax law which lowered the corporate tax rate from 35% to 21% beginning 1/1/2018. The decrease in our expected future tax rate results in a reduction in the value of our deferred tax assets by $49,369. As we have a full valuation allowance against our deferred tax asset, a corresponding decrease in our valuation allowance is also required. 161 The following table summarizes the Company's capital losses and net operating losses as of December 31, 2017 that can be applied against future taxable profit. Country Canada Canada Canada United States United States Type Non-capital losses Allowable Capital losses Investment Tax Credits Net operating losses Capital losses Amount $ 31,159 3,285 1,211 250,518 54,399 Expiry Date 2027 - 2035 None 2023 - 2026 2026 - 2035 2019 Utilization of the United States loss carry forwards will be limited in any year as a result of previous changes in ownership. For the Energy Fuels Holding Corporation and Subsidiaries consolidated group, management estimates that approximately $75 million in net operating losses will expire unutilized as a result of these limitations. Utilization of the Canadian loss carry forwards will be subject to the Acquisition of Control Rules in any year as a result of previous changes in ownership. 17. SUPPLEMENTAL FINANCIAL INFORMATION The components of revenues are as follows: The Company has three major customers to which its sales for the year were as follows: 2017 - $13.08 million; $6.99 million; $4.40 million; (2016 (three major customers) - $33.36 million; $8.69 million; $7.00 million); (2015 (four major customers) - $20.98 million; $16.31 million; $12.53 million; $9.00 million). The Company’s revenues by country of customer for the current year were as follows: 2017 - $20.07 million - U.S.; Other - $4.40 million; (2016 - $50.76 million - U.S.; Other - $3.69 million) (2015 -$37.85 million - U.S.; $20.98 million - South Korea; Other - $1.87 million). Deferred revenue at December 31, 2017 of $2.47 million (2016 - $2.34 million) relates to proceeds received on delivery of alternate feed materials in advance of the required processing activity. The components of other income (expense) are as follows: Years ended December 31, 2016 2015 2017 Interest income $ 161 $ 143 $ Change in value of investments accounted at fair value Change in value of warrant liabilities Change in value of convertible debentures Gain on settlement of loans and borrowings Insurance settlement Sales and property tax refunds Gain on sale of mineral properties Sale of surplus assets Other Other income (expense) 509 784 (940) — — — — 1,913 142 — 420 (407) 424 223 176 316 — (96) $ 2,569 $ 1,199 $ 94 38 590 (1,548) — — — — — 406 (420) 162 The components of accounts payable and accrued liabilities are as follows: Accounts payable Payroll liabilities Other accrued liabilities Accounts payable and accrued liabilities 18. COMMITMENTS AND CONTINGENCIES General legal matters December 31, 2017 December 31, 2016 $ $ 762 $ 835 4,852 6,449 $ 1,150 1,374 3,232 5,756 Other than routine litigation incidental to our business, or as described below, the Company is not currently a party to any material pending legal proceedings that management believes would be likely to have a material adverse effect on our financial position, results of operations or cash flows. White Mesa Mill In November 2012, the Company was served with a Plaintiff’s Original Petition and Jury Demand in the District Court of Harris County, Texas, claiming unspecified damages from the disease and injuries resulting from mesothelioma from exposure to asbestos, which the Plaintiff claims was contributed to by being exposed to asbestos products and dust while working at the White Mesa Mill. The Company does not consider this claim to have any merit, and therefore does not believe it will materially affect our financial position, results of operations or cash flows. In January, 2013, the Company filed a Special Appearance challenging jurisdiction and certain other procedural matters relating to this claim. This action was dismissed on February 21, 2018 and the matter is now finished. In January, 2013, the Ute Mountain Ute tribe filed a Petition to Intervene and Request for Agency Action challenging the Corrective Action Plan approved by the State of Utah Department of Environmental Quality (“UDEQ”) relating to nitrate contamination in the shallow aquifer at the White Mesa Mill site. This challenge is currently being evaluated, and may involve the appointment of an administrative law judge to hear the matter. The Company does not consider this action to have any merit. If the petition is successful, the likely outcome would be a requirement to modify or replace the existing Corrective Action Plan. At this time, the Company does not believe any such modification or replacement would materially affect our financial position, results of operations or cash flows. However, the scope and costs of remediation under a revised or replacement Corrective Action Plan have not yet been determined and could be significant. In April 2014, the Grand Canyon Trust filed a citizen suit in federal District Court for alleged violations of the Clean Air Act at the White Mesa Mill. In October 2014, the plaintiffs were granted leave by the Court to add further purported violations to their April 2014 suit. The Complaint, as amended, alleged that radon from one of the White Mesa Mill’s tailings impoundments exceeded the standard; that the White Mesa Mill is in violation of a requirement that only two tailings impoundments may be in operation at any one time; and that certain other violations related to the manner of measuring and reporting radon results from one of the tailings impoundments occurred in 2013. The Complaint asked the Court to impose injunctive relief, civil penalties of up to $38,000 per day per violation, costs of litigation including attorneys’ fees, and other relief. The Company believes the issues raised in the Complaint are being addressed through the proper regulatory channels and that we are currently in compliance with all applicable regulatory requirements relating to those matters. The Company intends to defend against all issues raised in the Complaint. Cross motions for summary judgment were heard by the District Court on November 17, 2016. On September 15, 2017, the Court issued its order in favor of the Company on all counts and dismissing the plaintiffs motions. This decision was not appealed by the plaintiffs, and the matter is now finished. Canyon Project In March, 2013, the Center for Biological Diversity, the Grand Canyon Trust, the Sierra Club and the Havasupai Tribe (the “Canyon Plaintiffs”) filed a complaint in the U.S. District Court for the District of Arizona (the “District Court”) against the Forest Supervisor for the Kaibab National Forest and the USFS seeking an order (a) declaring that the USFS failed to comply with environmental, mining, public land, and historic preservation laws in relation to our Canyon Project, (b) setting aside any approvals regarding exploration and mining operations at the Canyon Project, and (c) directing operations to cease at the Canyon Project and enjoining the USFS from allowing any further exploration or mining-related activities at the Canyon Project until the USFS fully complies with all applicable laws. In April 2013, the Plaintiffs filed a Motion for Preliminary Injunction, which was denied by the District Court in September, 2013. On April 7, 2015, the District Court issued its final ruling on the merits in favor of the 163 Defendants and the Company and against the Canyon Plaintiffs on all counts. The Canyon Plaintiffs appealed the District Court’s ruling on the merits to the Ninth Circuit Court of Appeals, and filed motions for an injunction pending appeal with the District Court. Those motions for an injunction pending appeal were denied by the District Court on May 26, 2015. Thereafter, Plaintiffs filed urgent motions for an injunction pending appeal with the Ninth Circuit Court of Appeals, which were denied on June 30, 2015. The hearing on the merits at the Court of Appeals was held on December 15, 2016. On December 12, 2017, the Ninth Circuit Court of Appeals issued its ruling on the merits in favor of the Defendants and the Company and against the Canyon Plaintiffs on all counts. The Canyon Plaintiffs have petitioned the Ninth Circuit Court of Appeals for a rehearing en banc. On February 21, 2018, the Court of Appeals ordered the Defendants and the Company to file a response to the Canyon Plaintiffs' petition for a rehearing en banc. If a rehearing is granted and the Canyon Plaintiffs are successful on their appeal on the merits, the Company may be required to maintain the Canyon Project on standby pending resolution of the matter. Such a required prolonged stoppage of shaft sinking and mining activities could have a significant impact on our future operations. Mineral property commitments The Company enters into commitments with federal and state agencies and private individuals to lease mineral rights. These leases are renewable annually and annual renewal costs are expected to total $1.37 million for the year ended December 31, 2018. Surety bonds The Company has indemnified third-party companies to provide surety bonds as collateral for the Company’s ARO. The Company is obligated to replace this collateral in the event of a default, and is obligated to repay any reclamation or closure costs due. The Company currently has $22.13 million posted against an undiscounted ARO of $43.46 million (December 2016 - $23.18 million posted against undiscounted asset retirement obligation of $43.00 million). Commitments The Company is contractually obligated under two long -term and two spot contracts to deliver 400,000 and 250,000 pounds of U3O8 respectively. 19. SEGMENT INFORMATION The Company is engaged in uranium extraction, recovery and sales of uranium from mineral properties and the recycling of uranium bearing materials generated by third parties. As a part of these activities the Company also acquires, explores, evaluates and, if warranted, permits uranium properties. The Company’s primary mining activities are in the United States. The reportable segments are those operations whose operating results are reviewed by the Chief Operating Decision Maker (CODM), the Chief Executive Officer for the Company to make decisions about resources to be allocated to the segment and assess its performance provided those operations pass certain quantitative thresholds. In order to determine any reportable operating segments, management reviewed various factors, including geographical location and managerial structure. It was determined by management that a reportable operating segment generally consists of an individual property managed by a single general manager and management team. The Company previously had two reportable segments, the conventional uranium recovery segment (the “Conventional Uranium Segment”) and the in-situ uranium recovery segment (the “ISR Uranium Segment”). The Conventional Uranium Segment The Conventional Uranium Segment consisted of a standalone conventional uranium recovery facility (the “White Mesa Mill”), conventional mining projects in the vicinity of the White Mesa Mill located in the Colorado Plateau, Henry Mountains, Arizona Strip, and the Roca Honda Project (“Roca Honda”) in New Mexico, and the Sheep Mountain Project (“Sheep Mountain”) in Wyoming. At December 31, 2017 the conventional mining projects in the vicinity of the White Mesa Mill, with the exception of shaft sinking and evaluation activities at the Company’s Canyon Mine Project, are on standby, being evaluated for continued mining activities and/or in process of being permitted. The White Mesa Mill also processes third party uranium-bearing mineralized materials from mining and recycling activities. The ISR Uranium Segment The ISR Uranium Segment consisted of an operating uranium recovery facility to recover concentrated uranium from wellfields of the Nichols Ranch Project located in Wyoming and a uranium recovery facility and wellfields maintained on standby as part of the Alta Mesa Project in Texas. The Nichols Ranch Project also includes the Jane Dough property and the Hank Project. Additionally, the segment includes other mineral properties in the vicinity of the Nichols Ranch Project and the Alta Mesa Project. 164 The Nichols Ranch Project and surrounding assets were acquired as part of the Company’s 2015 acquisition of Uranerz Energy Corporation and the Alta Mesa Project was acquired in June of 2016. Change in segment reporting Due to changes during 2017 in how uranium is delivered under contractual requirements, the Company reevaluated its segment presentation. Key factors for establishing two operating segments at the time were each segment had a vice president of operations, sales contracts for each segment were satisfied by the output of the respective segment, no commingling of finished product and the expectation was that higher prices would expand each segment's opportunities. At the time the CODM was receiving internal reporting including, operating profits for each segment, capital allocations for the development of each segment, contract revenue for each segment stayed with the segment and cost reporting per pound. During 2017, due to the changes above, the Company has concluded it has only one reportable segment. The Company has re- negotiated its primary remaining sales contract to allow deliveries from for any produced material (versus it originally required deliveries only from ISR materials sourced from Nichols Ranch production) and the contract is now filled with material from the White Mesa Mill. Nichols Ranch uranium is now finished at the White Mesa Mill, where originally it was completed at a third party facility. At this time the CODM does not receive any internal reporting including operating profits by location and is not making capital recommendations by location. 20. UNAUDITED SUPPLEMENTARY QUARTERLY INFORMATION The following table summarizes unaudited supplementary quarterly information for the two years ended December 31, 2017, and 2016: Net loss Net loss per share Weighted average shares outstanding Basic and Diluted Three months ended March 31, 2017 June 30, 2017 September 30, 2017 December 31, 2017 (unaudited) (in thousands, except share and per share amounts) $ $ (10,596) $ (0.15) $ (4,480) $ (0.06) $ (4,884) $ (0.07) $ (8,030) (0.11) 70,220 70,567 71,963 74,367 Three months ended December 31, March 31, 2016 2016 (unaudited) (in thousands, except share and per share amounts) September 30, 2016 June 30, 2016 Net loss Net loss per share Weighted average shares outstanding Basic and Diluted $ $ (8,865) $ (10,441) $ (0.19) $ (0.20) $ (8,245) $ (0.14) $ (12,313) (0.19) 47,660,414 53,043,512 58,630,457 66,205,153 21. FAIR VALUE ACCOUNTING Assets and liabilities measured at fair value on a recurring basis The following tables set forth the fair value of the Company's assets and liabilities measured at fair value on a recurring basis (at least annually) by level within the fair value hierarchy as at December 31, 2017. As required by accounting guidance, assets and liabilities are classified in their entirety based on the lowest level of input that is significant to the fair value measurement. 165 As at December 31, 2017, the fair values of cash and cash equivalents, restricted cash, short-term deposits, receivables, accounts payable and accrued liabilities approximate their carrying values because of the short-term nature of these instruments. Investments Warrant liabilities (Note 13) Convertible debentures (Note 12) Level 1 Level 2 Level 3 Total $ 1,937 $ — $ — $ (2,991) (16,636) (385) — — — $ (17,690) $ (385) $ — $ 1,937 (3,376) (16,636) (18,075) The Company's investments are marketable equity securities which are exchange traded, and are valued using quoted market prices in active markets and as such are classified within Level 1 of the fair value hierarchy. The fair value of the investments is calculated as the quoted market price of the marketable equity security multiplied by the quantity of shares held by the Company. Assets and liabilities measured at fair value on a non-recurring basis In the year ended December 31, 2015, the Company recorded an impairment charge of $47.73 million associated with the Goodwill recognized in the acquisition of Uranerz on June 18, 2015. The estimated fair value used in the December 31, 2015 impairment analysis was determined using discounted cash flow projections. Key assumptions used in the calculation of recoverable amounts include discount rates, uranium prices, future timing of production volume including the date when a mineral property can be brought into production and the expected cost to produce uranium and future care and maintenance and operating costs. In the second quarter of 2015, the Company recorded the fair value of Nichols Ranch Project upon acquisition of Uranerz. The estimated fair value used in the June 18, 2015 valuation was determined using discounted cash flow projections and various other pricing scenarios. Key assumptions used in the calculation of recoverable amounts include discount rates, uranium prices, future timing of production volume including the date when a mineral property can be brought into production and the expected cost to produce uranium, future care and maintenance and operating costs as well as precedent market transactions data. The following table sets forth a summary of the quantitative and qualitative information related to the unobservable inputs used in the calculation of the Company's non-recurring Level 3 fair value measurements for the year ended December 31, 2017 and 2016. 166 Date of Fair Value Measurement Valuation Technique Unobservable Input Range/Weighted Average For the years ended December 31, 2017 and 2016 Nichols Ranch Project and mineral properties in the ISR and Conventional segments December 31, 2015 Nichols Ranch Project June 18, 2015 Acquired Uranerz exploration properties June 18, 2015 and December 31, 2015 Discount Rate Short and Long Term Uranium Price United States Inflation Rate Discount Rate Short and Long Term Uranium Price United States Inflation Rate Precedent Transaction Research Discounted Cash Flow Model Discounted Cash Flow Model Enterprise value to resource model and acreage multiple 10% $38.90 to $62.10 2% 10% $37.95 to $65.00 2% Measured and Indicated pounds U3O8 - 2.00x Inferred Pounds U3O8 - 1.5x $77.0x - Acre 167 22. RELATED PARTY TRANSACTIONS On May 17, 2017, the Board of Directors of the Company appointed Robert W. Kirkwood and Benjamin Eshleman III to the Board of Directors of the Company. Mr. Kirkwood is a principal of the Kirkwood Companies, including Kirkwood Oil and Gas LLC, Wesco Operating, Inc., and United Nuclear LLC (“United Nuclear”). United Nuclear, owns a 19% interest in the Company’s Arkose Mining Venture while the Company owns the remaining 81%. The Company acts as manager of the Arkose Mining Venture and has management and control over operations carried out by the Arkose Mining Venture. The Arkose Mining Venture is a contractual joint venture governed by a venture agreement dated as of January 15, 2008 entered into by Uranerz Energy Corporation (a subsidiary of the Company) and United Nuclear (the “Venture Agreement”). United Nuclear contributed $0.37 million to the expenses of the Arkose Joint Venture based on the approved budget for the twelve months ended December 31, 2017. Mr. Benjamin Eshleman III is President of Mesteña LLC, which became a shareholder of the Company through the Company’s acquisition of Mesteña Uranium, L.L.C (now Alta Mesa LLC) in June 2016 through the issuance of 4,551,284 common shares of the Company to the direction of the Sellers (of which 4,303,032 common shares of the Company are currently held by the Sellers). In connection with the Purchase Agreement, one of the Acquired Companies, Leoncito Project, L.L.C. entered into an Amended and Restated Uranium Testing Permit and Lease Option Agreement with Mesteña Unproven, Ltd., Jones Ranch Minerals Unproven, Ltd and Mesteña Proven, Ltd. (collectively the “Grantors”), which requires Leoncito Project, L.L.C., to make a payment in the amount of $0.60 million to the Grantors in June 2019 (of which up to 50% may be paid in common shares of the Company at the Company’s election). At December 31, 2017, the Company has accrued $0.30 million of this liability on the balance sheet. The Grantors are managed by Mesteña LLC. Pursuant to the Purchase Agreement, the Alta Mesa Properties held by the Acquired Companies are subject to a royalty of 3.125% of the value of the recovered U3O8 from the Alta Mesa Properties sold at a price of $65.00 per pound or less, 6.25% of the value of the recovered U3O8 from the Alta Mesa Properties sold at a price greater than $65.00 per pound and up to and including $95.00 per pound, and 7.5% of the value of the recovered U3O8 from the Alta Mesa Properties sold at a price greater than $95.00 per pound. The royalties are held by the Sellers, and Mr. Eshleman and his extended family hold all of the ownership interests in the Sellers. In addition, Mr. Eshleman and certain members of his extended family are parties to surface use agreements that entitle them to surface use payments from the Acquired Companies in certain circumstances. The Alta Mesa Properties are currently being maintained on care and maintenance to enable the Company to restart operations as market conditions warrant. Due to the price of U3O8, the Company did not pay any royalty payments or surface use payments to the Sellers or to Mr. Eshleman or his immediate family members in the year ended December 31, 2017 and does not anticipate paying any royalty payments or surface use payments to the Sellers or to Mr. Eshleman or his immediate family members during the remainder of 2017. Pursuant to the Purchase Agreement, surface use payments from June 2016 through December 31, 2018 have been deferred until June 30, 2019 at which time the Company will pay $1.35 million to settle this obligation. As of December 31, 2017, the Company has accrued $0.81 million of this liability on the balance sheet. 23. SUBSEQUENT EVENTS Issuance of stock options and RSUs On January 23, 2018 the Company granted 0.42 million stock options with an exercise price of $1.70 and 0.88 million RSU’s to its employees, directors and consultants.$1.70. The options carry a five-year life and are vested as follows: 50% immediately; 25% on January 23, 2019; 25% on January 23, 2020. The RSU’s vest as follows: 50% on January 27, 2019; 25% on January 27, 2020; and 25% on January 27, 2021. Sale of shares in the Company's ‘At-the-Market’ program (“ATM”). From January 1, 2018 through March 8, 2018, the Company has issued 0.39 million shares for proceeds $0.65 million using the ATM. ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND FINANCIAL DISCLOSURE The required disclosure related to our previous change in auditor can be found in our Current Report on Form 8-K filed with the SEC on March 29, 2017. 168 Evaluation of Disclosure Controls and Procedures ITEM 9A. CONTROLS AND PROCEDURES As of the end of the period covered by this Annual Report on Form 10-K, an evaluation was carried out under the supervision of and with the participation of the Company’s management, including the Chief Executive Officer (“CEO”) and Chief Financial Officer (“CFO”), of the effectiveness of the design and operation of the Company’s disclosure controls and procedures (as defined in Rule 13a – 15(e) and Rule 15d – 15(e) under the Exchange Act). Based on that evaluation, the CEO and the CFO have concluded that as of the end of the period covered by this Annual Report on Form 10-K, the Company’s disclosure controls and procedures were effective in ensuring that: (i) information required to be disclosed by the Company in reports that it files or submits to the SEC under the Exchange Act is recorded, processed, summarized and reported within the time periods specified in applicable rules and forms; and (ii) material information required to be disclosed in its reports filed under the Exchange Act is accumulated and communicated to its management, including its CEO and CFO, as appropriate, to allow for accurate and timely decisions regarding required disclosure. It should be noted that while the CEO and CFO believe that the Company’s disclosure controls and procedures provide a reasonable level of assurance that they are effective, they do not expect that the Company’s disclosure controls and procedures or internal control over financial reporting will prevent all errors and fraud. A control system, no matter how well conceived or operated, can provide only reasonable, not absolute, assurance that the objectives of the control system are met. Management’s Report on Internal Control over Financial Reporting Management is responsible for establishing and maintaining adequate internal control over financial reporting, as defined in Rule 13a-15(f) under the Exchange Act. The Company’s management has employed a framework consistent with Exchange Act Rule 13a-15(c), to evaluate the Company’s internal control over financial reporting described below. A company’s internal control over financial reporting is a process designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles. A company’s internal control over financial reporting includes those policies and procedures that: (i) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of the assets of the company; (ii) provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with generally accepted accounting principles, and that receipts and expenditures of the company are being made only in accordance with authorizations of management and directors of the company; and (iii) provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use, or disposition of the Company’s assets that could have a material effect on the financial statements. It should be noted that a control system, no matter how well conceived or operated, can only provide reasonable assurance, not absolute assurance, that the objectives of the control system are met. Also, projections of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate because of changes in conditions, or that the degree of compliance with policies and procedures may deteriorate. The senior executive officers, including the Company’s CEO and CFO, conducted an evaluation of the effectiveness, design and operation of the Company’s internal control over financial reporting as of December 31, 2017, based on the criteria established in Internal Control – Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission 2013 framework. This evaluation included review of the documentation of controls, evaluation of the design effectiveness of controls, testing of the operating effectiveness of controls and a conclusion on this evaluation. Based on this evaluation, management has concluded that the Company’s internal control over financial reporting was effective as of December 31, 2017 and no material weaknesses were discovered. It should be noted that while the Company’s CEO and CFO believe that the Company’s internal controls over financial reporting provide a reasonable level of assurance that they are effective, they do not expect that the Corporation’s internal controls over financial reporting will prevent all errors and fraud. Attestation Report of the Registered Public Accounting Firm This Annual Report on Form 10-K does not include an attestation report of the Company’s registered independent public accounting firm regarding internal control over financial reporting. Management’s report was not subject to attestation by the Company’s registered independent public accounting firm as the Company qualifies as an “emerging growth company” under the Jumpstart Our Business Start-ups Act of 2012. 169 Changes in Internal Control Over Financial Reporting During the quarter ended December 31, 2017, there were no changes in the Company’s internal control over financial reporting that materially affected, or are likely to materially affect, the Company’s internal control over financial reporting. None. ITEM 9B. OTHER INFORMATION. 170 PART III ITEM 10. DIRECTORS, EXECUTIVE OFFICERS AND CORPORATE GOVERNANCE Information relating to this item will be included in the proxy statement for our 2018 Annual Meeting of Shareholders and is incorporated by reference in this report. Information relating to this item will be included in the proxy statement for our 2018 Annual Meeting of Shareholders and is incorporated by reference in this report. ITEM 11. EXECUTIVE COMPENSATION ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT AND RELATED STOCKHOLDER MATTERS Information relating to this item will be included in the proxy statement for our 2018 Annual Meeting of Shareholders and is incorporated by reference in this report. ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS AND DIRECTOR INDEPENDENCE Information relating to this item will be included in the proxy statement for our 2018 Annual Meeting of Shareholders and is incorporated by reference in this report. ITEM 14. PRINCIPAL ACCOUNTANT FEES AND SERVICES Information relating to this item will be included in the proxy statement for our 2018 Annual Meeting of Shareholders and is incorporated by reference in this report. ITEM 15. EXHIBITS AND FINANCIAL STATEMENT SCHEDULES Documents Filed as Part of This Report. (1) Financial Statements Report of Independent Registered Public Accounting Firm Consolidated Balance Sheets at December 31, 2017 and 2016 Consolidated Statements of Operations Comprehensive Loss for the years ended December 31, 2017, 2016 and 2015 Consolidated Statements of Operations Comprehensive Loss for the years ended December 31, 2017, 2016 and 2015 Consolidated Statements of Changes in Equity Consolidated Statements of Cash Flows for the years ended December 31, 2017, 2016, and 2015 Notes to the Consolidated Financial Statements 171 (2) Financial Statement Schedules Schedules are omitted and are not applicable or not required, or the required information is shown in the financial statements or notes thereto. 172 (3) Exhibits Where an exhibit is filed by incorporation by reference to a previously filed registration statement or report, such registration statement or report is identified in parentheses. Exhibit No. Document Description 1.1 1.2 1.3 3.1 3.2 3.3 4.1 4.2 4.3 4.4 4.5 4.6 4.7 4.8 4.9 Underwriting Agreement by and among the Company, Cantor Fitzgerald Canada Corporation, Haywood Securities Inc. and Roth Capital Partners, LLC dated March 9, 2016. (1) Underwriting Agreement by and among the Company, Cantor Fitzgerald Canada Corporation and Rodman & Renshaw (a unit of H.C. Wainwright & Co. LLC) dated September 14, 2016. (2) Amended and Restated Underwriting Agreement by and among the Company, Cantor Fitzgerald Canada Corportion and Rodman & Renshaw (a unit of H.C. Wainwright & Co. LLC) dated September 15, 2016.(3) Articles of Continuance dated September 2, 2005.(4) Articles of Amendment dated May 26, 2006.(5) Bylaws.(6) The Amended and Restated Convertible Debenture Indenture dated August 4, 2016 between Energy Fuels Inc., BNY Trust Company of Canada and the Bank of New York Mellon providing for the issuance of debentures.(7) Financing Agreement between Johnson County, Wyoming and Uranerz Energy Corporation dated November 26, 2013.(8) Bond Purchase Agreement among the State of Wyoming, Johnson County and Uranerz Energy Corporation dated November 12, 2013.(9) Promissory Note among the State of Wyoming, Johnson County and Uranerz Energy Corporation dated November 26, 2013.(10) Mortgage, Assignment of Revenues, Security Agreement, Fixture Filing and Financing Statement between Uranerz Energy Corporation and UMB Bank, n.a. as Trustee and Mortgagee dated November 26, 2013.(11) Shareholder Rights Plan between Energy Fuels Inc., and CIBC Mellon Trust Company dated February 3, 2009. (12) Warrant Indenture between Energy Fuels Inc. and CST Trust Company providing for the issue of common share purchase warrants dated March 14, 2016.(13) First Supplemental Indenture among Energy Fuels Inc., CST Trust Company and American Stock Transfer & Trust Company, LLC dated April 14, 2016.(14) Warrant Indenture between Energy Fuels Inc., CST Trust Company and American Stock Transfer & Trust Company, LLC dated September 20, 2016.(15) 10.1 Energy Fuels 2013 Amended and Restated Stock Option Plan.(16) 173 Exhibit No. 10.2 Energy Fuels Inc. Omnibus Compensation Plan dated January 28, 2015.(17) Document Description 10.3 Sales Agreement between Energy Fuels Inc. and Cantor Fitzgerald & Co. dated December 23, 2016.(18) 10.4 Form of Indemnity Agreement between Energy Fuels and its officers and directors.(19) 10.5 Amended and Restated Employment Agreement between Energy Fuels Inc., Energy Fuels Resources (USA) Inc. and Stephen P. Antony dated August 4, 2016.(20) 10.6 Employment Agreement between Energy Fuels Inc. and David C. Frydenlund effective March 2, 2018 10.7 Employment Agreement between Energy Fuels Inc. and W. Paul Goranson effective February 14, 2018 10.8 Employment Agreement between Energy Fuels Inc. and Mark S. Chalmers effective April 14, 2016.(21) 10.9 Employment Agreement between Energy Fuels Inc. and Mark S. Chalmers effective February 1, 2018 10.10 Amendment No. 1 to the Sales Agreement between Energy Fuels Inc. and Cantor Fitzgerald & Co. dated December 23, 2016.(22) 10.11 Professional Services Agreement between Energy Fuels Inc. and Daniel G. Zang dated March 2, 2018 21.1 An organizational chart showing Energy Fuels Inc.’s direct and indirect subsidiaries 23.1 Consent of KPMG LLP, Independent Registered Public Accountants, U.S. 23.2 Consent of Roscoe Postle Associates Inc. 23.3 Consent of William E. Roscoe 23.4 Consent of Douglas H. Underhill 23.5 Consent of Thomas C. Pool 23.6 Consent of Robert Michaud 23.7 Consent of Stuart E. Collins 23.8 Consent of Mark B. Mathisen 23.9 Consent of Harold R. Roberts 23.10 Consent of David A. Ross 23.11 Consent of Peters Geosciences 174 Exhibit No. Document Description 23.12 Consent of Douglas C. Peters 23.13 Consent of BRS Inc. 23.14 Consent of Douglas L. Beahm 23.15 Consent of W. Paul Goranson 23.16 Consent of Douglass Graves 23.17 Consent of John H. White, III 23.18 Consent of Don R. Woody 23.19 Consent of Trec, Inc. 23.20 Consent of Woody Enterprises 23.21 Consent of Allan Moran 23.22 Consent of Frank A. Daviess 23.23 Consent of SRK Consulting (U.S.) Inc. 23.24 Consent of Christopher Moreton 23.25 Consent of Valerie Wilson 23.26 Consent of Jeffrey Woods 23.27 Consent of KPMG LLP, Independent Registered Public Accountants, Canada 31.1 Certification of Chief Executive Officer pursuant to Rule 13a-14(a) of the Exchange Act 31.2 Certification of Chief Financial Officer pursuant to Rule 13a-14(a) of the Exchange Act 32.1 32.2 Certification of Chief Executive Officer pursuant to Rule 13a-14(b) of the Exchange Act and 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 Certification of Chief Financial Officer pursuant to Rule 13a-14(b) of the Exchange Act and 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 95.1 Mine Safety Disclosure (1) Incorporated by reference to Exhibit 10.1 to Energy Fuels' Form 8-K filed March 10, 2016. 175 (2) Incorporated by reference to Exhibit 1.1 to Energy Fuels' Form 8-K filed on September 16, 2016. (3) Incorporated by reference to Exhibit 1.2 of Energy Fuels’ Form 8-K filed with the SEC on September 16, 2016. (4) Incorporated by reference to Exhibit 3.1 of Energy Fuels’ Form F-4 filed with the SEC on May 8, 2015. (5) Incorporated by reference to Exhibit 3.2 of Energy Fuels’ Form F-4 filed with the SEC on May 8, 2015. (6) Incorporated by reference to Exhibit 3.3 of Energy Fuels’ Form F-4 filed with the SEC on May 8, 2015. (7) Incorporated by reference to Exhibit 4.1 to Energy Fuels’ Form 10-Q filed with the SEC on August 5, 2016. (8) Incorporated by reference to Exhibit 4.1 to the Form 8-K filed on December 3, 2013 by Uranerz Energy Corporation. (9) Incorporated by reference to Exhibit 4.2 to the Form 8-K filed on December 3, 2013 by Uranerz Energy Corporation. (10) Incorporated by reference to Exhibit 4.3 to the Form 8-K filed on December 3, 2013 by Uranerz Energy Corporation. (11) Incorporated by reference to Exhibit 4.4 to the Form 8-K filed on December 3, 2013 by Uranerz Energy Corporation. (12) Incorporated by reference to Exhibit 10.9 to Energy Fuels’ Form F-4 filed on May 8, 2015. (13) Incorporated by reference to Exhibit 4.1 to Energy Fuels’ Form 8-K filed on March 14, 2016. (14) Incorporated by reference to Exhibit 4.1 to Energy Fuels’ Form 8-K filed on April 20, 2016. (15) Incorporated by reference to Exhibit 4.1 to Energy Fuels’ Form 8-K filed on September 20, 2016. (16) Incorporated by reference from Schedule B of Exhibit 99.84 of Energy Fuels' registration statement on Form 40-F filed with the SEC on November 15, 2013. (17) Incorporated by reference to Exhibit 4.1 to Energy Fuels’ Form S-8 filed on June 24, 2015. (18) Incorporated by reference to Exhibit 1.1 to Energy Fuels’ Form 8-K filed on December 23, 2016. (19) Incorporated by reference to Exhibit 10.4 to Energy Fuels’ Form 10-K filed with the SEC on March 15, 2016. (20) Incorporated by reference to Exhibit 10.5 to Energy Fuels’ Form 10-Q filed with the SEC on August 5, 2016. (21) Incorporated by reference to Exhibit 10.11 to Energy Fuels’ Form 10-Q filed with the SEC on May 6, 2016. (22) Incorporated by reference to Exhibit 1.1 to Energy Fuels’ Form 8-K filed with the SEC on December 29, 2017. None. ITEM 16. FORM 10-K SUMMARY 176 Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized. SIGNATURES ENERGY FUELS INC. By: /s/ Mark S. Chalmers Mark S. Chalmers, President & Chief Executive Officer Principal Executive Officer Date: March 9, 2018 177 In accordance with the Securities Exchange Act, this report has been signed below by the following persons on behalf of the registrant and in the capacities and on the dates indicated. Per: /s/ Mark S. Chalmers Mark S. Chalmers, President & Chief Executive Officer (Principal Executive Officer) and Director Date: March 9, 2018 Per: /s/ David C. Frydenlund David C. Frydenlund, Chief Financial Officer (Principal Financial Officer) Date: March 9, 2018 Per: /s/ Matthew Tarnowski Matthew Tarnowski, Chief Accounting Officer & Controller Date: March 9, 2018 Per: /s/ Benjamin Eshleman Benjamin Eshleman, Director Date: March 9, 2018 Per: /s/ Dennis Higgs Dennis Higgs, Director Date: March 9, 2018 Per: /s/ J. Birks Bovaird J. Birks Bovaird, Director Date: March 9, 2018 Per: /s/ Bruce D. Hansen Bruce D. Hansen, Director Date: March 9, 2018 Per: /s/ Robert Kirkwood Robert Kirkwood, Director Date: March 9, 2018 Per: /s/ Paul Carroll Paul A. Carroll, Director Date: March 9, 2018 178 EMPLOYMENT AGREEMENT THIS EMPLOYMENT AGREEMENT (“Agreement”) is effective as of the 2nd day of March, 2018 (the “Effective Date”), by and between Energy Fuels Resources (USA) Inc., a Delaware corporation (“EFRI”), Energy Fuels Inc., an Ontario corporation (“EFI”) (EFRI and EFI are collectively referred to herein as the “Company”) and David C. Frydenlund (“Employee”). In consideration of the agreements contained in this Agreement, and other good and valuable consideration, the receipt and sufficiency of which are hereby acknowledged, the Company and Employee hereby agree as follows: ARTICLE 1 EMPLOYMENT, REPORTING AND DUTIES 1.1. Employment. The Company hereby employs and engages the services of Employee to serve as Chief Financial Officer, General Counsel and Corporate Secretary and Employee agrees to diligently and competently serve as and perform the functions of Chief Financial Officer, General Counsel and Corporate Secretary for the compensation and benefits stated herein. A copy of Employee’s current job description is attached hereto as Exhibit A, and Company and Employee agree and acknowledge that, subject to Section 4.2(b), Company retains the right to reasonably add to, or remove, duties and responsibilities set forth in that job description as business or other operating reasons may arise for changes to occur. It is understood that Employee will be appointed an officer of EFI and EFRI during the term of this Agreement, but that Employee’s direct employment relationship will be as an employee of EFRI. 1.2. Fulltime Service. Excluding any periods of vacation and sick leave to which Employee may be entitled, Employee agrees to devote Employee’s full time and energies to the responsibilities with the Company consistent with past practice and shall not, during the Term of this Agreement, be engaged in any business activity which would interfere with or prevent Employee from carrying out Employee’s duties under this Agreement. ARTICLE 2 COMPENSATION AND RELATED ITEMS 2.1. Compensation. As compensation and consideration for the services to be rendered by Employee under this Agreement, the Company agrees to pay Employee and Employee agrees to accept: (a) Base Salary and Benefits. A base salary (“Base Salary”) of $270,864 per annum, less required tax withholding, which shall be paid in accordance with the Company’s standard payroll practice. Employee’s Base Salary may be increased from time to time (but not 1 decreased, including after any increase, without Employee’s written consent), at the discretion of the Company, and after any such change, Employee’s new level of Base Salary shall be Employee’s Base Salary for purposes of this Agreement until the effective date of any subsequent change. Employee shall also receive benefits such as health insurance, vacation and other benefits consistent with the then applicable Company benefit plans to the same extent as other employees of the Company with similar position or level. Employee understands and agrees that, subject to Sections 2.1(b) and (c) below, Company’s benefit plans may, from time to time, be modified or eliminated at Company’s discretion. (b) Cash Bonus. A cash bonus opportunity (the “Cash Bonus”) during each calendar year with a target (the “Target Cash Bonus”) equal to forty percent (40)% (the “Target Cash Bonus Percentage”) of Employees’ Base Salary for the year in which the cash bonus is paid, such cash bonus to be paid in accordance with the Company’s existing Short Term Incentive Plan, as such plan may be amended or replaced from time to time, or the equivalent (the “STIP”). Pursuant to the terms of the STIP, each annual Cash Bonus shall be payable based on the achievement of performance goals, and may be higher or lower than the Target Cash Bonus based on achievement of those goals. For each calendar year during the term of this Agreement, the Board (or the Compensation Committee) of EFI will determine and will establish in writing (i) the applicable STIP performance goals, which shall be reasonably achievable and if achieved would result in payment of the Target Cash Bonus, (iii) the percentage of annual Base Salary to be payable to Employee if some lesser or greater percentage of the annual STIP performance goals are achieved, and (iv) such other applicable terms and conditions of the STIP necessary to satisfy the requirements of Section 409A (“Section 409A”) of the Internal Revenue Code of 1986, as amended (the "Code"); and (c) Equity Award. An equity award opportunity (the “Equity Award”) during each calendar year with a target value (the “Target Equity Award”) equal to eighty percent (80)% (the “Target Equity Award Percentage”) of Employee’s Base Salary for the year in which the award is granted, such equity award to be awarded in accordance with the Company’s existing Long Term Incentive Plan, as such plan may be amended or replaced from time to time, or the equivalent (the “LTIP”). Pursuant to the terms of the LTIP, each annual equity award shall be made based on the achievement of performance goals, and may be higher or lower than the Target Equity Award based on achievement of those goals. For each calendar year during the term of this Agreement, the Board (or the Compensation Committee) of EFI will determine and will establish in writing (i) the applicable LTIP performance goals, which shall be reasonably achievable and if achieved would result in payment of the Target Equity Award, (iii) the percentage of annual Base Salary value to be awarded in equity to Employee if some lesser or greater percentage of the annual LTIP performance goals are achieved, and (iv) such other applicable terms and conditions of the LTIP necessary to satisfy the requirements of Section 409A of the Code. 2.2. Annual Medical. The Company will reimburse Employee for the cost of a comprehensive annual medical examination for each year of this Agreement, provided that 2 Employee requests such reimbursement and such reimbursement is made no later than the last day of the calendar year following the calendar year in which the examination expense was incurred. Employee will promptly notify the President & CEO if the annual medical examination reveals any condition which, if untreated, is likely to interfere with Employee’s ability to perform the essential requirements of his or her position, and if requested by the President & CEO, Employee will provide the details of the condition and the potential impact on his or her ability to perform the essential requirements of his or her position to enable the President & CEO to determine how best to accommodate Employee and protect the critical business interests of the Company. 2.3. Expenses. The Company agrees that Employee shall be allowed reasonable and necessary business expenses in connection with the performance of Employee’s duties within the guidelines established by the Company as in effect at any time with respect to key employees (“Business Expenses”), including, but not limited to, reasonable and necessary expenses for food, travel, lodging, entertainment and other items in the promotion of the Company within such guidelines. The Company shall promptly reimburse Employee for all reasonable Business Expenses incurred by Employee upon Employee’s presentation to the Company of an itemized account thereof, together with receipts, vouchers, or other supporting documentation. 2.4. Vacation. Employee will be entitled to four weeks of vacation each year, in addition to the 10 paid holidays each year. Carry over from one year to the next will be as per the Company’s paid leave policy. 2.5. Use of Company Vehicle. Employee will be provided the full time use of a suitable vehicle for travel between the Lakewood office and home as well as for business travel to field sites as required, or the equivalent. ARTICLE 3 TERMINATION 3.1. Term. Employee’s employment under this Agreement shall commence on the Effective Date and will end on the date (the “Initial Expiration Date”) that is the second anniversary of the Effective Date, unless terminated sooner under the provisions of this Article, or extended under the terms of this Section. If neither Company nor Employee provides written notice of intent not to renew this Agreement by ninety (90) days prior to the Initial Expiration Date, this Agreement shall be automatically renewed for twelve (12) additional months, and if neither Company nor Employee provides written notice of intent not to renew this Agreement prior to ninety (90) days before the end of such additional 12-month period, this Agreement shall continue to be automatically renewed for successive additional 12-month periods until such time either Company or Employee provides written notice of intent not to renew prior to ninety (90) days before the end of any such renewal period. 3 3.2. Termination of Employment. Except as may otherwise be provided herein, Employee’s employment under this Agreement may terminate upon the occurrence of: (a) Notice by Company. The termination date specified in a written notice of termination that is given by the Company to Employee; (b) Notice by Employee. Thirty (30) days after written notice of termination is given by Employee to the Company; (c) Employee’s becoming disabled; Death or Disability. Employee’s death or, at the Company’s option, upon (d) Deemed Termination Without Just Cause upon a Change of Control. A deemed termination without just cause under Section 4.1(a) upon the occurrence of a Change of Control; or (e) Notice Not to Renew. If the Company or Employee gives the other a notice not to renew this Agreement under Section 3.1, employment under this Agreement shall terminate at the close of business at the end of the Initial Expiration Date or at the end of the 12-month renewal period in which timely notice not to renew was given, as the case may be. A notice by the Company not to renew shall be considered a notice of termination, resulting in the Company terminating Employee’s employment under this Agreement. Any notice of termination given by the Company to Employee under Section 3.2(a) or (e) above shall specify whether such termination is with or without just cause as defined in Section 3.4. Any notice of termination given by Employee to the Company under Section 3.2(b) above shall specify whether such termination is made with or without Good Reason as defined in Section 4.2(b). 3.3. Obligations of the Company Upon Termination. (a) With Just Cause/Without Good Reason. If the Company terminates Employee’s employment under this Agreement with just cause as defined in Section 3.4, or if Employee terminates his employment without Good Reason as defined in Section 4.2(b), in either case whether before or after a Change of Control as defined in Section 4.2(a), then Employee’s employment with the Company shall terminate without further obligation by the Company to Employee, other than payment of all accrued obligations (“Accrued Obligations”), including outstanding Base Salary, accrued vacation pay and any other cash benefits accrued up to and including the date of termination. That payment shall be made in one lump sum, less required tax withholding, within ten (10) working days after the effective date of such termination. Employee will have up to the earlier of: (A) ninety (90) days from the effective date of termination of Employee’s employment; or (B) the date on which the exercise period of the particular stock option expires, to exercise only that portion of the stock options previously granted to Employee that have 4 not been exercised, but which have vested, and thereafter Employee’s stock options will expire and Employee will have no further right to exercise the stock options. Any stock options held by Employee that are not yet vested at the termination date immediately expire and are cancelled and forfeited to the Company on the termination date. Any Restricted Stock Units (“RSUs”) held by Employee that have vested on or before the termination date shall be paid (or the shares issuable thereunder issued) to Employee. Any RSUs held by Employee that are not vested on or before the termination date will be immediately cancelled and forfeited to the Company on the termination date. The rights of Employee upon termination in respect of any other awards granted to Employee under any of the Company’s equity compensation plans shall be as set forth in such plans or in the award agreement for any such awards, as applicable. Notwithstanding the foregoing, on retirement, Employee will have up to the earlier of: (A) one hundred and eighty (180) days from the effective date of retirement; or (B) the date on which the exercise period of the particular stock option expires, to exercise only that portion of the stock options previously granted to Employee that have not been exercised, but which have vested, and thereafter Employee’s stock options will expire and Employee will have no further right to exercise the stock options. (b) With Good Reason/Without Just Cause/Disabled/Death. If Employee terminates Employee’s employment under this Agreement for Good Reason as defined in Section 4.2(b), or if the Company terminates Employee’s employment without just cause as defined in Section 3.4, or if the Company terminates Employee’s employment by reason of Employee becoming Disabled as defined in Section 3.5, or if Employee dies (in which case the date of Employee’s death shall be considered his or her termination date), in any case whether before or after a Change of Control as defined in Section 4.2(a), or if there is a deemed termination without just cause upon a Change of Control as contemplated by Section 4.1(a), then Employee’s employment with the Company shall terminate, as of the effective date of the termination, and in lieu of any other severance benefit that would otherwise be payable to Employee: (i) the Company shall pay the following amounts to Employee (or, in the case of termination by reason of Employee becoming Disabled or upon the death of Employee, to Employee’s legal representative or estate as applicable) after the effective date of such termination, or in a manner and at such later time as specified by Employee (or Employee’s legal representative), and agreed to by the Company, subject to being in compliance with Section 409A of the Code: (A) all Accrued Obligations, less required tax withholding, up to and including the date of termination, to be paid on the date of termination of employment, or within no more than five (5) working days thereafter, and the Company will reimburse the Employee for all proper expenses incurred by the Employee in discharging his responsibilities to the Company prior to the effective date of termination of the Employee’s employment in accordance with Section 2.3 above; and 5 (B) an amount in cash equal to one and one half (1.5) (the “Severance Factor”) times the sum of Employee’s Base Salary, Target Cash Bonus and Target Equity Award for the full year in which the Date of Termination occurs, less required tax withholding, such amount to be paid within thirty (30) calendar days after the date Employee signs the Release contemplated by Section 3.7; (ii) Employee or Employee’s legal representative will have up to the earlier of: (A) ninety (90) days from the effective date of termination of Employee’s employment for all cases other than the death of Employee and twelve (12) months from the effective date of termination of Employee’s employment in the case of death of Employee; or (B) the date on which the exercise period of the particular stock option expires, to exercise only that portion of the stock options previously granted to Employee that have not been exercised, but which have vested, and thereafter Employee’s stock options will expire and Employee or his or her legal representative will have no further right to exercise the stock options. Subject to Section 4.1(c), any stock options held by Employee that are not yet vested at the termination date immediately expire and are cancelled and forfeited to the Company on the termination date. Any RSUs held by Employee that have vested on or before the termination date shall be paid (or the shares issuable thereunder issued) to Employee or his or her legal representative or estate as applicable. Subject to Section 4.1(c), any RSUs held by Employee that are not vested on or before the termination date will be immediately cancelled and forfeited to the Company on the termination date. Subject to Section 4.1(c), the rights of Employee or his or her legal representative or estate as applicable upon termination in respect of any other awards granted to Employee under any of the Company’s equity compensation plans shall be as set forth in such plans or in the award agreement for any such awards, as applicable; (iii) Upon termination, the Company or its Successor (as defined in Section 4.1(a)), agrees to reimburse Employee the full cost of the COBRA continuation rate charged for employee and dependent coverage, through the EFRI Health and Welfare Plan on a monthly basis, for a period of months equal to twelve times the Severance Factor (the “Coverage Period”), beyond Employee’s termination month. Employee and his or her dependents may, at their choosing, enroll in the COBRA continuation plan through EFRI for the first eighteen months following Employee’s termination month or, if they choose, they may enroll in a separate plan of their choosing, by using the reimbursement to enroll in medical and 6 prescription insurance of their choosing. Reimbursement at the rate described herein will continue for the Coverage Period beyond Employee’s termination month, but beginning with the nineteenth month, Employee and his or her dependents will need to obtain coverage from a different source than the COBRAcontinuation plan through EFRI. The reimbursement will be to Employee and his or her dependents directly, and will be grossed up so that there is no negative tax impact to the Employee or his or dependents for coverage of the premiums charged by the insurance carriers for the COBRA continuation coverage for the current month of reimbursement. The reimbursed cost of COBRA coverage will be indexed annually, and will match the rate charged for any month of coverage available by the insurance carrier for Medical, Dental, and Optical coverage through EFRI for employee and spouse coverage. Both Employee and his or her dependents, will have the option of purchasing a medical plan separate from the plan offered by EFRI; and (iv) Nothing herein shall preclude the Company from granting additional severance benefits to Employee upon termination of employment. Notwithstanding the foregoing, in the case of Disability, any Base Salary payable to Employee during the one hundred and eighty (180) day period of disability will be reduced by the amount of any disability benefits Employee receives or is entitled to receive as a result of any disability insurance policies for which the Company has paid the premiums. (c) Section 280G. Notwithstanding any other provisions of this Agreement, or any other plan, arrangement or agreement to the contrary, if any of the payments or benefits provided or to be provided by the Company or its affiliates to Employee or for Employee’s benefit pursuant to the terms of this Agreement or otherwise (“Covered Payments”) constitute “parachute payments” within the meaning of Section 280G of the Code and would, but for this Section 3.3(c) be subject to the excise tax imposed under Section 4999 of the Code (or any successor provision thereto) or any similar tax imposed by state or local law or any interest or penalties with respect to such taxes (collectively, the “Excise Tax”), then the following shall apply: (i) If the Covered Payments, reduced by the sum of (1) the Excise Tax and (2) the total of the Federal, state, and local income and employment taxes payable by Employee on the amount of the Covered Payments which are in excess of three times Employee’s “base amount” within the meaning of Section 280(G) of the Code less one dollar (the “Threshold Amount”), are greater than or equal to the Threshold Amount, Employee shall be entitled to the full benefits payable under this Agreement; and (ii) If the Threshold Amount is less than (1) the Covered Payments, but greater than (2) the Covered Payments reduced by the sum of (x) the Excise Tax and 7 (y) the total of the Federal, state, and local income and employment taxes on the amount of the Covered Payments which are in excess of the Threshold Amount, then the Covered Payments shall be reduced (but not below zero) to the extent necessary so that the sum of all Covered Payments shall not exceed the Threshold Amount. In such event, the Covered Payments shall be reduced in the following order: (A) cash payments not subject to Section 409A; (B) cash payments subject to Section 409A; (C) equity-based payments and acceleration; and (D) non-cash forms of benefits. To the extent any payment is to be made over time (e.g., in installments, etc.), then the payments shall be reduced in reverse chronological order. The determination as to which of the alternative provisions of Section 3.3(c)(ii) shall apply to Employee shall be made by a nationally recognized accounting firm selected by the Company (the “Accounting Firm”), which shall provide detailed supporting calculations both to the Company and Employee within 15 business days of the date of termination, if applicable, or at such earlier time as is reasonably requested by the Company or Employee. For purposes of determining which of the alternative provisions of Section 3.3(c)(ii) shall apply, Employee shall be deemed to pay Federal income taxes at the highest marginal rate of Federal income taxation applicable to individuals for the calendar year in which the determination is to be made, and state and local income taxes at the highest marginal rates of individual taxation in the state and locality of Employee’s residence on the date of termination, net of the maximum reduction in Federal income taxes which could be obtained from deduction of such state and local taxes. Any determination by the Accounting Firm shall be binding upon the Company and Employee. 3.4. Definition of Just Cause. As used in this Agreement, the term “just cause” will mean any one or more of the following events: (a) theft, fraud, dishonesty, or misappropriation by Employee involving the property, business or affairs of the Company or the discharge of Employee’s responsibilities or the exercise of his or her authority; (b) willful misconduct or the willful failure by Employee to properly discharge his or her responsibilities or to adhere to the policies of the Company; (c) Employee’s gross negligence in the discharge of his or her responsibilities or involving the property, business or affairs of the Company to the material detriment of the Company; (d) Employee’s conviction of a criminal or other statutory offence that constitutes a felony or which has a potential sentence of imprisonment greater than six (6) months or Employee’s conviction of a criminal or other statutory offence involving, in the sole discretion of the Board of Directors of EFI, moral turpitude; 8 (e) (f) or 6 below; Employee’s material breach of a fiduciary duty owed to the Company; any material breach by Employee of the covenants contained in Articles 5 (g) Employee’s unreasonable refusal to follow the lawful written direction of the President and Chief Executive Officer of the Company on any material matter; (h) any conduct of Employee which, in the reasonable opinion of the President and Chief Executive Officer of the Company or Board of Directors of EFI, is materially detrimental or embarrassing to the Company; or (i) any other conduct by Employee that would constitute “just cause” as that term is defined at law. The Company must provide written notice to Employee prior to termination for just cause pursuant to Section 3.4 (c), (f), (g), (h), or (i) and provide Employee the opportunity to correct and cure the failure within thirty (30) days from the receipt of such notice. If the parties disagree as to whether the Company had just cause to terminate the Employee’s employment, the dispute will be submitted to binding arbitration pursuant to Section 7.10 below. 3.5. Definition of Disabled. As used herein, “Disabled” shall mean a mental or physical impairment which, in the reasonable opinion of a qualified doctor selected by mutual agreement of the Company and Employee acting reasonably, renders Employee unable, with reasonable accommodation, to perform with reasonable diligence the essential functions and duties of Employee on a full-time basis in accordance with the terms of this Agreement, which inability continues for a period of not less than 180 consecutive days. The providing of service to the Company for up to two (2) three (3) day periods during the one hundred and eighty (180) day period of disability will not affect the determination as to whether Employee is Disabled and will not restart the one hundred and eighty (180) day period of disability. If any dispute arises between the parties as to whether Employee is Disabled, Employee will submit to an examination by a physician selected by the mutual agreement of the Company and Employee acting reasonably, at the Company’s expense. The decision of the physician will be certified in writing to the Company, and will be sent by the Physician to Employee or Employee’s legally authorized representative, and will be conclusive for the purposes of determining whether Employee is Disabled. If Employee fails to submit to a medical examination within twenty (20) days after the Company’s request, Employee will be deemed to have voluntarily terminated his or her employment. 3.6. Return of Materials; Confidential Information. In connection with Employee’s separation from employment for any reason, Employee shall return any and all physical property belonging to the Company, and all material of whatever type containing “Confidential Information” as defined in Section 5.2 below, including, but not limited to, any and all documents, whether in 9 paper or electronic form, which contain Confidential Information, any customer information, production information, manufacturing-related information, pricing information, files, memoranda, reports, pass codes/access cards, training or other reference manuals, Company vehicle, telephone, gas cards or other Company credit cards, keys, computers, laptops, including any computer disks, software, facsimile machines, memory devices, printers, telephones, pagers or the like. 3.7. Delivery of Release. Within ten (10) working days after termination of Employee’s employment, and as a condition for receipt of payments set forth in Section 3.3(b)(i)(B), 3.3(b)(iii), and 4.1(a), the Company shall provide to Employee, or Employee’s legal representative, a form of written release, which form shall be satisfactory to the Company and generally consistent with the form of release used by the Company prior to such termination of employment (the “Release”) and which shall provide a full release of all claims against the Company and its corporate affiliates, except where Employee has been named as a defendant in a legal action arising out of the performance of Employee’s responsibilities in which case the Release will exempt any claims which Employee or his or her legal representative or estate may have for indemnity by the Company with respect to any such legal action. As a condition to the obligation of the Company to make the payments provided for in such Sections Employee, or Employee’s legal representative, shall execute and deliver the Release to the Company within the time periods provided for in said release. 3.8. Costs of Relocation to Canada on a Termination. In the event of any termination, and in addition to all other amounts payable to Employee hereunder, the Company will reimburse all Employee’s direct costs of relocating from Denver to Vancouver, provided such relocation occurs within 14 months from the date of termination of Employee’s employment hereunder. This would include the costs associated with the sale of Employee’s residence in Denver (i.e., reasonable realtor commissions and legal, documentation and filing fees associated therewith), cost of moving personal possessions and family members (including the cost of airplane tickets for Employee and Employee’s immediate family for one air flight) and a lump sum payment to cover estimated U.S. or Canadian income taxes payable on the relocation costs paid to you. Employee will discuss with the Company and consider any legitimate planning methods for the minimization of any such taxes. This will not include any costs associated with the purchase of a new residence in Canada, or any temporary lodging expenses in Canada or Denver. This paragraph will also apply to relocation from Denver to another location in Canada other than Vancouver, but only to the extent such costs do not exceed the costs that would apply to a relocation to Vancouver. Notwithstanding the foregoing, this clause will not apply to the extent the costs contemplated in this clause are paid by another employer. 10 ARTICLE 4 CHANGE OF CONTROL 4.1. Effect of Change of Control. In the event of a Change of Control of EFI during the term of this Agreement, or any renewal of this Agreement the following provisions shall apply: (a) If upon the Change of Control (i) Employee is not retained by EFI or its successor (whether direct or indirect, by purchase of assets, merger, consolidation, exchange of securities, amalgamation, arrangement or otherwise) to all or substantially all of the business and/or assets of EFI (“Successor”) on the same terms and conditions as set out in this Agreement and in circumstances that would not constitute Good Reason (where Good Reason is determined by reference to Employee’s employment status prior to the Change of Control and prior to any other event that could constitute Good Reason); and/or (ii) any such Successor does not, by agreement in form and substance satisfactory to Employee, expressly assume and agree to perform this Agreement in the same manner and to the same extent that EFI would be required to perform it if no such succession had taken place, then Employee shall be deemed to be terminated without just cause upon such Change of Control and shall be entitled to the compensation and all other rights specified in Article 3 in the same amount and on the same terms as if terminated without just cause as set out therein, subject to the additional rights set out in paragraph (c) below; (b) All rights of Employee in this Agreement, including without limitation all rights to severance and other rights upon a termination with or without cause, with or without Good Reason, upon a disability or upon death under Article 3 of this Agreement shall continue after a Change of Control in the same manner as before the Change of Control, subject to the additional rights set out in paragraph (c) below; (c) if, (i) there is a deemed termination without cause under Section 4.1(a); or (ii) within twelve (12) months following the effective date of the Change of Control, EFI, or its successor, terminates the employment of Employee without just cause or by reason of Disability, or Employee terminates his or her employment under this Agreement for Good Reason, 11 then, in addition to the other rights Employee has under this Agreement, and notwithstanding any other provision in this Agreement, all of the stock options previously granted to Employee that have neither vested nor expired will automatically vest and become immediately exercisable, any period of restriction and other restrictions imposed on all RSUs shall lapse, and all RSUs shall be immediately settled and payable, and all other securities awarded shall vest and/or accelerate in accordance with Article 16 of the EFI Omnibus Equity Incentive Plan or the comparable provisions of any other equity incentive plan under which such securities may have been issued. Employee will have ninety (90) days from the effective date of the termination of Employee’s employment to exercise any stock options which had vested as of the effective date of termination and thereafter Employee’s stock options will expire and Employee will have no further right to exercise the stock options. 4.2. Definitions of Change of Control and Good Reason. For the purposes of this Agreement, (a) “Change of Control” will mean the happening of any of the following events: (i) any transaction at any time and by whatever means pursuant to which (A) EFI goes out of existence by any means, except for any corporate transaction or reorganization in which the proportionate voting power among holders of securities of the entity resulting from such corporate transaction or reorganization is substantially the same as the proportionate voting power of such holders of EFI voting securities immediately prior to such corporate transaction or reorganization or (B) any Person (as defined in the Securities Act (Ontario)) or any group of two or more Persons acting jointly or in concert (other than EFI, a wholly-owned Subsidiary of EFI, an employee benefit plan of EFI or of any of its wholly-owned Subsidiaries (as defined in the Securities Act (Ontario)), including the trustee of any such plan acting as trustee) hereafter acquires the direct or indirect “beneficial ownership” (as defined by the Business Corporations Act (Ontario)) of, or acquires the right to exercise control or direction over, securities of EFI representing 50% or more of EFI’s then issued and outstanding securities in any manner whatsoever, including, without limitation, as a result of a take-over bid, an exchange of securities, an amalgamation of EFI with any other entity, an arrangement, a capital reorganization or any other business combination or reorganization; (ii) the sale, assignment or other transfer of all or substantially all of the assets of EFI in one or a series of transactions, whether or not related, to a Person or any group of two or more Persons acting jointly or in concert, other than a wholly- owned Subsidiary of EFI; (iii) the dissolution or liquidation of EFI except in connection with the distribution of assets of EFI to one or more Persons which were wholly-owned Subsidiaries of EFI immediately prior to such event; 12 (iv) the occurrence of a transaction requiring approval of EFI’s shareholders whereby EFI is acquired through consolidation, merger, exchange of securities, purchase of assets, amalgamation, arrangement or otherwise by any other Person (other than a short form amalgamation or exchange of securities with a wholly-owned Subsidiary of EFI); (v) a majority of the members of the Board of Directors of EFI are replaced or changed as a result of or in connection with any: (A) take-over bid, consolidation, merger, exchange of securities, amalgamation, arrangement, capital reorganization or any other business combination or reorganization involving or relating to EFI; (B) sale, assignment or other transfer of all or substantially all of the assets of EFI in one or a series of transactions, or any purchase of assets; or (C) dissolution or liquidation of EFI; (vi) during any two-year period, a majority of the members of the Board of Directors of EFI serving at the date of this Agreement is replaced by directors who are not nominated and approved by the Board of Directors of EFI; (vii) an event set forth in (i), (ii), (iii), (iv), (v) or (vi) has occurred with respect to EFRI or any of its direct or indirect parent companies, in which case the term “EFI” in those paragraphs will be read to mean “EFRI or such parent company” and the phrase “wholly-owned Subsidiary(ies)” will be read to mean “Affiliate(s) or wholly-owned Subsidiary(ies)”; or (viii) the Board of Directors of EFI passes a resolution to the effect that, an event set forth in (i), (ii), (iii), (iv), (v), (vi) or (vii) above has occurred. (b) “Good Reason” means, without the written agreement of Employee, there (i) a material reduction or diminution in the level of responsibility, or office of Employee, provided that before any claim of material reduction or diminution of responsibility may be relied upon by Employee, Employee must have provided written notice to Employee’s supervisor and the EFI’s Board of Directors of the alleged material reduction or diminution of responsibility and have given EFI at least thirty (30) calendar days within which to cure the alleged material reduction or diminution of responsibility; and provided further that ceasing to be the Chief Financial Officer of the Company shall not constitute a material reduction or diminution in the level of responsibility, or office of Employee, if Employee is retained at a comparable level of responsibility and office, such as in the office of “Chief Legal Officer and Corporate Secretary” or the equivalent, and continues to report directly to the President and Chief Executive Officer of the Company; 13 is: (ii) a reduction in the Employee’s Base Salary, Target Cash Bonus Percentage or Target Equity Award Percentage; or (iii) a proposed, forced relocation of Employee to another geographic location greater than fifty (50) miles from Employee’s office location at the time a move is requested after a Change of Control. ARTICLE 5 CONFIDENTIALITY 5.1. Position of Trust and Confidence. Employee acknowledges that in the course of discharging his or her responsibilities, he or she will occupy a position of trust and confidence with respect to the affairs and business of the Company and its customers and clients, and that he or she will have access to and be entrusted with detailed confidential information concerning the present and contemplated mining and exploration projects, prospects, and opportunities of the Company. Employee acknowledges that the disclosure of any such confidential information to the competitors of the Company or to the general public would be highly detrimental to the best interests of the Company. Employee further acknowledges and agrees that the right to maintain such detailed confidential information constitutes a proprietary right which the Company is entitled to protect. 5.2. Definition of Confidential Information. In this Agreement, “Confidential Information” means any information disclosed by or on behalf of the Company to Employee or developed by Employee in the performance of his or her responsibilities at any time before or after the execution of this Agreement, and includes any information, documents, or other materials (including, without limitation, any drawings, notes, data, reports, photographs, audio and/or video recordings, samples and the like) relating to the business or affairs of the Company or its respective customers, clients or suppliers that is confidential or proprietary, whether or not such information: (i) is reduced to writing; (ii) was created or originated by an employee; or (iii) is designated or marked as “Confidential” or “Proprietary” or some other designation or marking. The Confidential Information includes, but is not limited to, the following categories of information relating to the Company: (a) information concerning the present and contemplated mining, milling, processing and exploration projects, prospects and opportunities, including joint venture projects, of the Company; 14 (b) information concerning the application for permitting and eventual development or construction of the Company’s properties, the status of regulatory and environmental matters, the compliance status with respect to licenses, permits, laws and regulations, property and title matters and legal and litigation matters; (c) information of a technical nature such as ideas, discoveries, inventions, improvements, trade secrets, now-how, manufacturing processes, specifications, writings and other works of authorship; (d) financial and business information such as the Company’s business and strategic plans, earnings, assets, debts, prices, pricing structure, volume of purchases or sales, production, revenue and expense projections, historical financial statements, financial projections and budgets, historical and projected sales, capital spending budgets and plans, or other financial data whether related to the Company’s business generally, or to particular products, services, geographic areas, or time periods; (e) supply and service information such as goods and services suppliers’ names or addresses, terms of supply or service contracts of particular transactions, or related information about potential suppliers to the extent that such information is not generally known to the public, and to the extent that the combination of suppliers or use of a particular supplier, although generally known or available, yields advantages to the Company, the details of which are not generally known; (f) marketing information, such as details about ongoing or proposed marketing programs or agreements by or on behalf of the Company, sales forecasts or results of marketing efforts or information about impending transactions; (g) personnel information relating to employees, contractors, or agents, such as personal histories, compensation or other terms of employment or engagement, actual or proposed promotions, hirings, resignations, disciplinary actions, terminations or reasons therefor, training methods, performance, or other employee information; (h) customer information, such as any compilation of past, existing or prospective customer’s names, addresses, backgrounds, requirements, records of purchases and prices, proposals or agreements between customers and the Company, status of customer accounts or credit, or related information about actual or prospective customers; (i) computer software of any type or form and in any stage of actual or anticipated development, including but not limited to, programs and program modules, routines and subroutines, procedures, algorithms, design concepts, design specifications (design notes, annotations, documentation, float charts, coding sheets, and the like), source codes, object code and load modules, programming, program patches and system designs; and 15 (j) all information which becomes known to Employee as a result of Employee’s employment by the Company, which Employee acting reasonably, believes or ought to believe is confidential or proprietary information from its nature and from the circumstances surrounding its disclosure to Employee. 5.3. Non-Disclosure. Employee, both during his or her employment and for a period of five (5) years after the termination of his or her employment irrespective of the time, manner or cause of termination, will: (a) retain in confidence all of the Confidential Information; (b) refrain from disclosing to any person including, but not limited to, customers and suppliers of the Company, any of the Confidential Information except for the purpose of carrying out Employee’s responsibilities with the Company, and (c) refrain from directly or indirectly using or attempting to use such Confidential Information in any way, except for the purpose of carrying out Employee’s responsibilities with the Company. Employee shall deliver promptly to the Company, at the termination of Employee’s employment, or at any other time at the Company’s request, without retaining any copies, all documents and other material in Employee’s possession relating, directly or indirectly, to any Confidential Information. It is understood that should Employee be subject to subpoena or other legal process to seek the disclosure of such Confidential Information, Employee will advise the Company of such process and provide the Company with the necessary information to seek to protect the Confidential Information. 5.4. Whistleblower Laws. The foregoing obligations of confidentiality set out in this Article 5 are subject to applicable whistleblower laws, which protect Employee’s right to provide information to governmental and regulatory authorities, including communications with the U.S. Securities and Exchange Commission about possible securities law violations. Notwithstanding any other provision in this Agreement, Employee is not required to seek the Company’s permission or notify the Company of any communications made in compliance with applicable whistleblower laws, and the Company will not consider any such communications to violate this Agreement or any other agreement between Employer and the Company or any Company policy by which Employee is bound. 16 ARTICLE 6 NON-SOLICITATION 6.1. Non-Solicitation. Employee agrees that during the period (the “Non-Solicitation Period”) commencing on the date of this Agreement and ending twelve (12) months after the effective date of the termination of Employee’s employment irrespective of the time, manner or cause of termination, Employee will not, either individually or in partnership or jointly or in conjunction with any other person, entity or organization, as principal, agent, consultant, contractor, employer, employee or in any other manner, directly or indirectly: (a) solicit business from any customer, client or business relation of the Company, or prospective customer, client or business relation that the Company was actively soliciting, whether or not Employee had direct contact with such customer, client or business relation, for the benefit or on behalf of any person, firm or corporation operating a business which competes with the Company, or attempt to direct any such customer, client or business relation away from the Company or to discontinue or alter any one or more of their relationships with the Company; or (b) hire or offer to hire or entice away or in any other manner persuade or attempt to persuade any officer, employee, consultant, independent contractor, agent, licensee, supplier, or business relation of the Company to discontinue or alter any one of their relationships with the Company. 6.2. Remedies for Breach of Restrictive Covenants. Employee acknowledges that in connection with Employee’s employment he or she will receive or will become eligible to receive substantial benefits and compensation. Employee acknowledges that Employee’s employment by the Company and all compensation and benefits from such employment will be conferred by the Company upon Employee only because and on the condition of Employee’s willingness to commit Employee’s best efforts and loyalty to the Company, including protecting the Company’s confidential information and abiding by the non-solicitation covenants contained in this Agreement. Employee understands that his obligations set out in Article 5 and this Article 6 will not unduly restrict or curtail Employee’s legitimate efforts to earn a livelihood following any termination of his or her employment with the Company. Employee agrees that the restrictions contained in Article 5 and this Article 6 are reasonable and valid and all defenses to the strict enforcement of these restrictions by the Company are waived by Employee. Employee further acknowledges that a breach or threatened breach by Employee of any of the provisions contained in Article 5 or this Article 6 would cause the Company irreparable harm which could not be adequately compensated in damages alone. Employee further acknowledges that it is essential to the effective enforcement of this Agreement that, in addition to any other remedies to which the Company may be entitled at law or in equity or otherwise, the Company will be entitled to seek and obtain, in a summary manner, from any Court having jurisdiction, interim, interlocutory, and permanent injunctive relief, specific performance and other equitable remedies, without bond or other security being required. In addition 17 to any other remedies to which the Company may be entitled at law or in equity or otherwise, in the event of a breach of any of the covenants or other obligations contained in this Agreement, the Company will be entitled to an accounting and repayment of all profits, compensation, royalties, commissions, remuneration or benefits which Employee directly or indirectly, has realized or may realize relating to, arising out of, or in connection with any such breach. Should a court of competent jurisdiction declare any of the covenants set forth in Article 5 or this Article 6 unenforceable, the court shall be empowered to modify and reform such covenants so as to provide relief reasonably necessary to protect the interests of the Company and Employee and to award injunctive relief, or damages, or both, to which the Company may be entitled. ARTICLE 7 GENERAL PROVISIONS 7.1. Governing Law. This Agreement shall be governed by and construed in accordance with the laws of the state of Colorado. 7.2. Assignability. This Agreement is personal to Employee and without the prior written consent of the Company shall not be assignable by Employee other than by will or the laws of descent and distribution. This Agreement shall inure to the benefit of and be enforceable by Employee’s legal representatives and heirs. This Agreement shall also inure to the benefit of and be binding upon the Company and its successors and assigns. 7.3. Withholding. The Company may withhold from any amounts payable under this Agreement such federal, state or local taxes as shall be required to be withheld pursuant to any applicable law or regulation. 7.4. Entire Agreement; Amendment. This Agreement constitutes the entire agreement and understanding between Employee and the Company with respect to the subject matter hereof and, except as otherwise expressly provided herein, supersedes any prior agreements or understandings, whether written or oral, with respect to the subject matter hereof, including without limitation all employment, severance or change of control agreements previously entered into between Employee and the Company. Except as may be otherwise provided herein, this Agreement may not be amended or modified except by subsequent written agreement executed by both parties hereto. 7.5. Section 409A. This Agreement is intended to comply with Section 409Ato the extent Section 409A is applicable to this Agreement. Notwithstanding any other provision of this Agreement to the contrary, this Agreement shall be interpreted, operated and administered by the Company in a manner consistent with such intention and to avoid the pre-distribution inclusion in income of amounts deferred under this Agreement and the imposition of any additional tax or interest with respect thereto. Notwithstanding any other provision of this Agreement to the contrary, to the 18 extent that any payment under this Agreement constitutes “nonqualified deferred compensation” under Section 409A, the following shall apply to the extent Section 409A is applicable to such payment: (a) Any payable that is triggered upon the Employee’s termination of employment shall be paid only if such termination of employment constitutes a “separation from service” under Section 409A; and (b) All expenses or other reimbursements paid pursuant to this Agreement that are taxable income to Employee shall be paid no later than the end of the calendar year next following the calendar year in which Employee incurs such expense. With regard to any provision herein that provides for reimbursement of costs and expenses or in-kind benefits, except as permitted by Section 409A, (a) the right to reimbursement or in-kind benefits shall not be subject to liquidation or exchange for another benefit, (b) the amount of expenses eligible for reimbursement, or in-kind benefits, provided during any taxable year shall not affect the expenses eligible for reimbursement, or in-kind benefits to be provided, in any other taxable year; and (c) such payments shall be made on or before the last day of Employee’s taxable year following the taxable year in which the expense occurred. For purposes of Section 409A, Employee’s right to receive installment payments of any severance amount, if applicable, shall be treated as a right to receive a series of separate and distinct payments. In the event that Employee is deemed on the date of termination to be a “specified employee” as defined in Section 409A, then with regard to any payment or the provision of any benefit that is subject to Section 409A and is payable on account of a separation from service (as defined in Section 409A), such payment or benefit shall be delayed for until the earlier of (a) the first business day of the seventh calendar month following such termination of employment, or (b) Employee’s death. Any payments delayed by reason of the prior sentence shall be paid in a single lump sum, without interest thereon, on the date indicated by the previous sentence and any remaining payments due under this Agreement shall be paid as otherwise provided herein. 7.6. Multiple Counterparts. This Agreement may be executed in multiple counterparts, each of which shall constitute an original, but all of which together shall constitute one Agreement. 7.7. Notices. Any notice provided for in this Agreement shall be deemed delivered upon deposit in the United States mails, registered or certified mail, addressed to the party to whom directed at the addresses set forth below or at such other addresses as may be substituted therefor by notice given hereunder. Notice given by any other means must be in writing and shall be deemed delivered only upon actual receipt. If to the Company: c/o Energy Fuels Resources (USA) Inc. 19 225 Union Blvd., Suite 600 Lakewood, CO 80228 Attention: President and Chief Executive Officer If to Employee: David C. Frydenlund 8228 Harbortown Place Lone Tree CO 80124 7.8. Waiver. The waiver of any term or condition of this Agreement, or any breach thereof, shall not be deemed to constitute the waiver of the same or any other term or condition of this Agreement, or any breach thereof. 7.9. Severability. In the event any provision of this Agreement is found to be unenforceable or invalid, such provision shall be severable from this Agreement and shall not affect the enforceability or validity of any other provision of this Agreement. If any provision of this Agreement is capable of two constructions, one of which would render the provision void and the other that would render the provision valid, then the provision shall have the construction that renders it valid.. 7.10. Arbitration of Disputes. Except for disputes and controversies arising under Articles 5 or 6 or involving equitable or injunctive relief, any dispute or controversy arising under or in connection with this Agreement shall be conducted in accordance with the Colorado Rules of Civil Procedure and, unless the parties mutually agree on an arbitrator shall be arbitrated by striking from a list of potential arbitrators provided by the Judicial Arbiter Group in Denver, Colorado. If the parties are unable to agree on an arbitrator, the arbitrator will be selected from a list of seven (7) potential arbitrators provided by the Judicial Arbiter Group in Denver. The Company and Employee will flip a coin to determine who will make the first strike. The parties will then alternate striking from the list until there is one arbitrator remaining, who will be the selected arbitrator. Unless the parties otherwise agree and subject to the availability of the arbitrator, the arbitration will be heard within sixty (60) days following the appointment, and the decision of the arbitrator shall be binding on Employee and the Company and will not be subject to appeal. Judgment may be entered on the arbitrator’s award in any court having jurisdiction. 7.11. Currency. Except as expressly provided in this Agreement, all amounts in this Agreement are stated and shall be paid in United States dollars ($US). 7.12. Company’s Maximum Obligations. The compensation set out in this Agreement represents the Company’s maximum obligations, and other than as set out herein, Employee will 20 not be entitled to any other compensation, rights or benefits in connection with Employee’s employment or the termination of Employee’s employment. 7.13. Full Payment; No Mitigation Obligation. The Company’s obligation to make the payments provided for in this Agreement and otherwise to perform its obligations hereunder shall be subject to any set-off, counterclaim, recoupment, defense or other claim, right or action which the Company may have against Employee. IN WITNESS WHEREOF, the parties have executed this Agreement as of the Effective Date. ENERGY FUELS INC. By: /s/ Mark S. Chalmers Name: Mark S. Chalmers Title: President and Chief Executive Officer Date: February 14, 2018 ENERGY FUELS RESOURCES (USA) INC. By: /s/ Mark S. Chalmers Name: Mark S. Chalmers Title: President and Chief Executive Officer Date: February 14, 2018 /s/ David C. Frydenlund By: Name: David C. Frydenlund Title: Chief Financial Officer, General Counsel and Corporate Secretary Date: February 14, 2018 21 EXHIBIT A JOB DESCRIPTION 1. As Chief Financial Officer: Employee shall be responsible for overseeing the financial activities of Energy Fuels Inc. and its subsidiaries. Essential duties and responsibilities include: • as requested by the CEO, contributing to the development and achievement of strategic objectives for the Company • overseeing the financial planning and budgeting processes for the organization • overseeing the preparation of the Company’ financial statements and MD&A and providing certification as required by applicable securities laws • overseeing the Company’s internal control procedures • along with the CEO, playing a key role in executing public and private market capital raising initiatives • as requested by the CEO, playing a role in the Company’s investor relations activities • managing relationships with potential lenders to the Company • as requested by the CEO, assisting the CEO with the identification, negotiating and execution of M&A and/or similar transactions • playing an integral role along with the CEO in developing and maintaining relationships with investment banking firms 2. As General Counsel and Corporate Secretary: Employee shall be responsible for the legal administration of Energy Fuels Inc. and its subsidiaries (“Energy Fuels”), the compliance with public company and stock exchange matters, the coordination of international and domestic business transactions, the evaluation of enterprise risks and generally, all domestic and international legal, regulatory and environmental matters relating to Energy Fuels. Employee will work closely with senior operations, regulatory and permitting personnel. Essential duties and responsibilities include: • managing all legal matters relating to Energy Fuels’ activities, including management of • all outside counsel retained by Energy Fuels supporting the CEO and senior management in all legal aspects of commercial, corporate, financing, M&A, planning and other matters • being responsible for all corporate secretarial matters for Energy Fuels, including: corporate maintenance of all entities; calling and holding all director and committee meetings for all such entities; calling and holding all shareholders meetings for all such entities ensuring compliance with all stock exchange and securities law requirements 22 maintaining appropriate corporate records for all such entities; and making all applicable corporate, securities law and stock exchange filings • ensuring that Energy Fuels’ operations are provided with the legal and regulatory support necessary to be able to operate in compliance with all applicable licenses, permits, laws and regulations, including providing training as necessary and ensuring that operations personnel are apprised of all applicable license, permit, legal and regulatory requirements and any changes thereto • • establishing strategies for dealing with state and federal regulatory agencies, and meeting with and negotiating with regulatory authorities, in coordination with senior operations, regulatory and permitting personnel reviewing license and permit applications, amendments and renewals for compliance with applicable legal and regulatory requirements, as necessary, and developing specific language for licenses, permits, negotiated consent agreements, orders, and other binding agreements affecting Energy Fuels’ operations, as necessary interpreting license and permit conditions, laws and regulations applicable to Energy Fuels’ operations and assisting operations personnel in interpreting such conditions, requirements and any changes thereto • • coordinating responses to “requests for information” and addressing matters of non- compliance with regulatory authorities, in coordination with senior operations, regulatory and permitting personnel • managing all litigation and legal and regulatory challenges 3. General: Employee shall report to the President and Chief Executive Officer of the Company. This position will be located in the Lakewood office with frequent travel. Performance is to be based on Performance Goals set under the Company’s STIP and LTIP, which will be evaluated once per year. 23 EMPLOYMENT AGREEMENT THIS EMPLOYMENT AGREEMENT (“Agreement”) is effective as of the 14th day of February, 2018 (the “Effective Date”), by and between Energy Fuels Resources (USA) Inc., a Delaware corporation (“EFRI”), Energy Fuels Inc., an Ontario corporation (“EFI”) (EFRI and EFI are collectively referred to herein as the “Company”) and William Paul Goranson (“Employee”). In consideration of the agreements contained in this Agreement, and other good and valuable consideration, the receipt and sufficiency of which are hereby acknowledged, the Company and Employee hereby agree as follows: ARTICLE 1 EMPLOYMENT, REPORTING AND DUTIES 1.1. Employment. The Company hereby employs and engages the services of Employee to serve as Chief Operating Officer, and Employee agrees to diligently and competently serve as and perform the functions of Chief Operating Officer for the compensation and benefits stated herein. A copy of Employee’s current job description is attached hereto as Exhibit A, and Company and Employee agree and acknowledge that, subject to Section 4.2(b), Company retains the right to reasonably add to, or remove, duties and responsibilities set forth in that job description as business or other operating reasons may arise for changes to occur. It is understood that Employee will be appointed an officer of EFI and EFRI during the term of this Agreement, but that Employee’s direct employment relationship will be as an employee of EFRI. 1.2. Fulltime Service. Excluding any periods of vacation and sick leave to which Employee may be entitled, Employee agrees to devote Employee’s full time and energies to the responsibilities with the Company consistent with past practice and shall not, during the Term of this Agreement, be engaged in any business activity which would interfere with or prevent Employee from carrying out Employee’s duties under this Agreement. ARTICLE 2 COMPENSATION AND RELATED ITEMS 2.1. Compensation. As compensation and consideration for the services to be rendered by Employee under this Agreement, the Company agrees to pay Employee and Employee agrees to accept: (a) Base Salary and Benefits. A base salary (“Base Salary”) of $270,864 per annum, less required tax withholding, which shall be paid in accordance with the Company’s standard payroll practice. Employee’s Base Salary may be increased from time to time (but not decreased, including after any increase, without Employee’s written consent), at the discretion of 1 the Company, and after any such change, Employee’s new level of Base Salary shall be Employee’s Base Salary for purposes of this Agreement until the effective date of any subsequent change. Employee shall also receive benefits such as health insurance, vacation and other benefits consistent with the then applicable Company benefit plans to the same extent as other employees of the Company with similar position or level. Employee understands and agrees that, subject to Sections 2.1(b) and (c) below, Company’s benefit plans may, from time to time, be modified or eliminated at Company’s discretion. (b) Cash Bonus. A cash bonus opportunity (the “Cash Bonus”) during each calendar year with a target (the “Target Cash Bonus”) equal to forty percent (40%) (the “Target Cash Bonus Percentage”) of Employees’ Base Salary for the year in which the cash bonus is paid, such cash bonus to be paid in accordance with the Company’s existing Short Term Incentive Plan, as such plan may be amended or replaced from time to time, or the equivalent (the “STIP”). Pursuant to the terms of the STIP, each annual Cash Bonus shall be payable based on the achievement of performance goals, and may be higher or lower than the Target Cash Bonus based on achievement of those goals. For each calendar year during the term of this Agreement, the Board (or the Compensation Committee) of EFI will determine and will establish in writing (i) the applicable STIP performance goals, which shall be reasonably achievable and if achieved would result in payment of the Target Cash Bonus, (iii) the percentage of annual Base Salary to be payable to Employee if some lesser or greater percentage of the annual STIP performance goals are achieved, and (iv) such other applicable terms and conditions of the STIP necessary to satisfy the requirements of Section 409A (“Section 409A”) of the Internal Revenue Code of 1986, as amended (the "Code"); and (c) Equity Award. An equity award opportunity (the “Equity Award”) during each calendar year with a target value (the “Target Equity Award”) equal to eighty percent (80%) (the “Target Equity Award Percentage”) of Employee’s Base Salary for the year in which the award is granted, such equity award to be awarded in accordance with the Company’s existing Long Term Incentive Plan, as such plan may be amended or replaced from time to time, or the equivalent (the “LTIP”). Pursuant to the terms of the LTIP, each annual equity award shall be made based on the achievement of performance goals, and may be higher or lower than the Target Equity Award based on achievement of those goals. For each calendar year during the term of this Agreement, the Board (or the Compensation Committee) of EFI will determine and will establish in writing (i) the applicable LTIP performance goals, which shall be reasonably achievable and if achieved would result in payment of the Target Equity Award, (iii) the percentage of annual Base Salary value to be awarded in equity to Employee if some lesser or greater percentage of the annual LTIP performance goals are achieved, and (iv) such other applicable terms and conditions of the LTIP necessary to satisfy the requirements of Section 409A of the Code. 2.2. Annual Medical. The Company will reimburse Employee for the cost of a comprehensive annual medical examination for each year of this Agreement, provided that Employee requests such reimbursement and such reimbursement is made no later than the last day 2 of the calendar year following the calendar year in which the examination expense was incurred. Employee will promptly notify the President & CEO if the annual medical examination reveals any condition which, if untreated is likely to interfere with Employee’s ability to perform the essential requirements of his or her position, and if requested by the President & CEO, Employee will provide the details of the condition and the potential impact on his or her ability to perform the essential requirements of his or her position to enable the President & CEO to determine how best to accommodate Employee and protect the critical business interests of the Company. 2.3. Expenses. The Company agrees that Employee shall be allowed reasonable and necessary business expenses in connection with the performance of Employee’s duties within the guidelines established by the Company as in effect at any time with respect to key employees (“Business Expenses”), including, but not limited to, reasonable and necessary expenses for food, travel, lodging, entertainment and other items in the promotion of the Company within such guidelines. The Company shall promptly reimburse Employee for all reasonable Business Expenses incurred by Employee upon Employee’s presentation to the Company of an itemized account thereof, together with receipts, vouchers, or other supporting documentation. 2.4. Vacation. Employee will be entitled to four weeks of vacation each year, in addition to the 10 paid holidays each year. Carry over from one year to the next will be as per the Company’s paid leave policy. 2.5. Use of Company Vehicle. Employee will be provided the full time use of a suitable vehicle for travel between the Lakewood office and home as well as for business travel to field sites as required, or the equivalent. ARTICLE 3 TERMINATION 3.1. Term. Employee’s employment under this Agreement shall commence on the Effective Date and will end on the date (the “Initial Expiration Date”) that is the second anniversary of the Effective Date, unless terminated sooner under the provisions of this Article, or extended under the terms of this Section. If neither Company nor Employee provides written notice of intent not to renew this Agreement by ninety (90) days prior to the Initial Expiration Date, this Agreement shall be automatically renewed for twelve (12) additional months, and if neither Company nor Employee provides written notice of intent not to renew this Agreement prior to ninety (90) days before the end of such additional 12-month period, this Agreement shall continue to be automatically renewed for successive additional 12-month periods until such time either Company or Employee provides written notice of intent not to renew prior to ninety (90) days before the end of any such renewal period. 3 3.2. Termination of Employment. Except as may otherwise be provided herein, Employee’s employment under this Agreement may terminate upon the occurrence of: (a) Notice by Company. The termination date specified in a written notice of termination that is given by the Company to Employee; (b) Notice by Employee. Thirty (30) days after written notice of termination is given by Employee to the Company; (c) Employee’s becoming disabled; Death or Disability. Employee’s death or, at the Company’s option, upon (d) Deemed Termination Without Just Cause upon a Change of Control. A deemed termination without just cause under Section 4.1(a) upon the occurrence of a Change of Control; or (e) Notice Not to Renew. If the Company or Employee gives the other a notice not to renew this Agreement under Section 3.1, employment under this Agreement shall terminate at the close of business at the end of the Initial Expiration Date or at the end of the 12-month renewal period in which timely notice not to renew was given, as the case may be. A notice by the Company not to renew shall be considered a notice of termination, resulting in the Company terminating Employee’s employment under this Agreement. Any notice of termination given by the Company to Employee under Section 3.2(a) or (e) above shall specify whether such termination is with or without just cause as defined in Section 3.4. Any notice of termination given by Employee to the Company under Section 3.2(b) above shall specify whether such termination is made with or without Good Reason as defined in Section 4.2(b). 3.3. Obligations of the Company Upon Termination. (a) With Just Cause/Without Good Reason. If the Company terminates Employee’s employment under this Agreement with just cause as defined in Section 3.4, or if Employee terminates his employment without Good Reason as defined in Section 4.2(b), in either case whether before or after a Change of Control as defined in Section 4.2(a), then Employee’s employment with the Company shall terminate without further obligation by the Company to Employee, other than payment of all accrued obligations (“Accrued Obligations”), including outstanding Base Salary, accrued vacation pay and any other cash benefits accrued up to and including the date of termination. That payment shall be made in one lump sum, less required tax withholding, within ten (10) working days after the effective date of such termination. Employee will have up to the earlier of: (A) ninety (90) days from the effective date of termination of Employee’s employment; or (B) the date on which the exercise period of the particular stock option expires, to exercise only that portion of the stock options previously granted to Employee that have 4 not been exercised, but which have vested, and thereafter Employee’s stock options will expire and Employee will have no further right to exercise the stock options. Any stock options held by Employee that are not yet vested at the termination date immediately expire and are cancelled and forfeited to the Company on the termination date. Any Restricted Stock Units (“RSUs”) held by Employee that have vested on or before the termination date shall be paid (or the shares issuable thereunder issued) to Employee. Any RSUs held by Employee that are not vested on or before the termination date will be immediately cancelled and forfeited to the Company on the termination date. The rights of Employee upon termination in respect of any other awards granted to Employee under any of the Company’s equity compensation plans shall be as set forth in such plans or in the award agreement for any such awards, as applicable. Notwithstanding the foregoing, on retirement, Employee will have up to the earlier of: (A) one hundred and eighty (180) days from the effective date of retirement; or (B) the date on which the exercise period of the particular stock option expires, to exercise only that portion of the stock options previously granted to Employee that have not been exercised, but which have vested, and thereafter Employee’s stock options will expire and Employee will have no further right to exercise the stock options. (b) With Good Reason/Without Just Cause/Disabled/Death. If Employee terminates Employee’s employment under this Agreement for Good Reason as defined in Section 4.2(b), or if the Company terminates Employee’s employment without just cause as defined in Section 3.4, or if the Company terminates Employee’s employment by reason of Employee becoming Disabled as defined in Section 3.5, or if Employee dies (in which case the date of Employee’s death shall be considered his or her termination date), in any case whether before or after a Change of Control as defined in Section 4.2(a), or if there is a deemed termination without just cause upon a Change of Control as contemplated by Section 4.1(a), then Employee’s employment with the Company shall terminate, as of the effective date of the termination, and in lieu of any other severance benefit that would otherwise be payable to Employee: (i) the Company shall pay the following amounts to Employee (or, in the case of termination by reason of Employee becoming Disabled or upon the death of Employee, to Employee’s legal representative or estate as applicable) after the effective date of such termination, or in a manner and at such later time as specified by Employee (or Employee’s legal representative), and agreed to by the Company, subject to being in compliance with Section 409A of the Code: (A) all Accrued Obligations, less required tax withholding, up to and including the date of termination, to be paid on the date of termination of employment, or within no more than five (5) working days thereafter, and the Company will reimburse the Employee for all proper expenses incurred by the Employee in discharging his responsibilities to the Company prior to the effective date of termination of the Employee’s employment in accordance with Section 2.3 above; and 5 (B) an amount in cash equal to one and one half (1.5) (the “Severance Factor”) times the sum of Employee’s Base Salary, Target Cash Bonus and Target Equity Award for the full year in which the Date of Termination occurs, less required tax withholding, such amount to be paid within thirty (30) calendar days after the date Employee signs the Release contemplated by Section 3.7; (ii) Employee or Employee’s legal representative will have up to the earlier of: (A) ninety (90) days from the effective date of termination of Employee’s employment for all cases other than the death of Employee and twelve (12) months from the effective date of termination of Employee’s employment in the case of death of Employee; or (B) the date on which the exercise period of the particular stock option expires, to exercise only that portion of the stock options previously granted to Employee that have not been exercised, but which have vested, and thereafter Employee’s stock options will expire and Employee or his or her legal representative will have no further right to exercise the stock options. Subject to Section 4.1(c), any stock options held by Employee that are not yet vested at the termination date immediately expire and are cancelled and forfeited to the Company on the termination date. Any RSUs held by Employee that have vested on or before the termination date shall be paid (or the shares issuable thereunder issued) to Employee or his or her legal representative or estate as applicable. Subject to Section 4.1(c), any RSUs held by Employee that are not vested on or before the termination date will be immediately cancelled and forfeited to the Company on the termination date. Subject to Section 4.1(c), the rights of Employee or his or her legal representative or estate as applicable upon termination in respect of any other awards granted to Employee under any of the Company’s equity compensation plans shall be as set forth in such plans or in the award agreement for any such awards, as applicable; (iii) Upon termination, the Company or its Successor (as defined in Section 4.1(a)), agrees to reimburse Employee the full cost of the COBRA continuation rate charged for employee and dependent coverage, through the EFRI Health and Welfare Plan on a monthly basis, for a period of months equal to twelve times the Severance Factor (the “Coverage Period”), beyond Employee’s termination month. Employee and his or her dependents may, at their choosing, enroll in the COBRA continuation plan through EFRI for the first eighteen months following Employee’s termination month or, if they choose, they may enroll in a separate plan of their choosing, by using the reimbursement to enroll in medical and 6 prescription insurance of their choosing. Reimbursement at the rate described herein will continue for the Coverage Period beyond Employee’s termination month, but beginning with the nineteenth month, Employee and his or her dependents will need to obtain coverage from a different source than the COBRAcontinuation plan through EFRI. The reimbursement will be to Employee and his or her dependents directly, and will be grossed up so that there is no negative tax impact to the Employee or his or dependents for coverage of the premiums charged by the insurance carriers for the COBRA continuation coverage for the current month of reimbursement. The reimbursed cost of COBRA coverage will be indexed annually, and will match the rate charged for any month of coverage available by the insurance carrier for Medical, Dental, and Optical coverage through EFRI for employee and spouse coverage. Both Employee and his or her dependents, will have the option of purchasing a medical plan separate from the plan offered by EFRI; and (iv) Nothing herein shall preclude the Company from granting additional severance benefits to Employee upon termination of employment. Notwithstanding the foregoing, in the case of Disability, any Base Salary payable to Employee during the one hundred and eighty (180) day period of disability will be reduced by the amount of any disability benefits Employee receives or is entitled to receive as a result of any disability insurance policies for which the Company has paid the premiums. (c) Section 280G. Notwithstanding any other provisions of this Agreement, or any other plan, arrangement or agreement to the contrary, if any of the payments or benefits provided or to be provided by the Company or its affiliates to Employee or for Employee’s benefit pursuant to the terms of this Agreement or otherwise (“Covered Payments”) constitute “parachute payments” within the meaning of Section 280G of the Code and would, but for this Section 3.3(c) be subject to the excise tax imposed under Section 4999 of the Code (or any successor provision thereto) or any similar tax imposed by state or local law or any interest or penalties with respect to such taxes (collectively, the “Excise Tax”), then the following shall apply: (i) If the Covered Payments, reduced by the sum of (1) the Excise Tax and (2) the total of the Federal, state, and local income and employment taxes payable by Employee on the amount of the Covered Payments which are in excess of three times Employee’s “base amount” within the meaning of Section 280(G) of the Code less one dollar (the “Threshold Amount”), are greater than or equal to the Threshold Amount, Employee shall be entitled to the full benefits payable under this Agreement; and (ii) If the Threshold Amount is less than (1) the Covered Payments, but greater than (2) the Covered Payments reduced by the sum of (x) the Excise Tax and 7 (y) the total of the Federal, state, and local income and employment taxes on the amount of the Covered Payments which are in excess of the Threshold Amount, then the Covered Payments shall be reduced (but not below zero) to the extent necessary so that the sum of all Covered Payments shall not exceed the Threshold Amount. In such event, the Covered Payments shall be reduced in the following order: (A) cash payments not subject to Section 409A; (B) cash payments subject to Section 409A; (C) equity-based payments and acceleration; and (D) non-cash forms of benefits. To the extent any payment is to be made over time (e.g., in installments, etc.), then the payments shall be reduced in reverse chronological order. The determination as to which of the alternative provisions of Section 3.3(c)(ii) shall apply to Employee shall be made by a nationally recognized accounting firm selected by the Company (the “Accounting Firm”), which shall provide detailed supporting calculations both to the Company and Employee within 15 business days of the date of termination, if applicable, or at such earlier time as is reasonably requested by the Company or Employee. For purposes of determining which of the alternative provisions of Section 3.3(c)(ii) shall apply, Employee shall be deemed to pay Federal income taxes at the highest marginal rate of Federal income taxation applicable to individuals for the calendar year in which the determination is to be made, and state and local income taxes at the highest marginal rates of individual taxation in the state and locality of Employee’s residence on the date of termination, net of the maximum reduction in Federal income taxes which could be obtained from deduction of such state and local taxes. Any determination by the Accounting Firm shall be binding upon the Company and Employee. 3.4. Definition of Just Cause. As used in this Agreement, the term “just cause” will mean any one or more of the following events: (a) theft, fraud, dishonesty, or misappropriation by Employee involving the property, business or affairs of the Company or the discharge of Employee’s responsibilities or the exercise of his or her authority; (b) willful misconduct or the willful failure by Employee to properly discharge his or her responsibilities or to adhere to the policies of the Company; (c) Employee’s gross negligence in the discharge of his or her responsibilities or involving the property, business or affairs of the Company to the material detriment of the Company; (d) Employee’s conviction of a criminal or other statutory offence that constitutes a felony or which has a potential sentence of imprisonment greater than six (6) months or Employee’s conviction of a criminal or other statutory offence involving, in the sole discretion of the Board of Directors of EFI, moral turpitude; 8 (e) (f) or 6 below; Employee’s material breach of a fiduciary duty owed to the Company; any material breach by Employee of the covenants contained in Articles 5 (g) Employee’s unreasonable refusal to follow the lawful written direction of the President and Chief Executive Officer of the Company on any material matter; (h) any conduct of Employee which, in the reasonable opinion of the President and Chief Executive Officer of the Company or Board of Directors of EFI, is materially detrimental or embarrassing to the Company; or (i) any other conduct by Employee that would constitute “just cause” as that term is defined at law. The Company must provide written notice to Employee prior to termination for just cause pursuant to Section 3.4 (c), (f), (g), (h), or (i) and provide Employee the opportunity to correct and cure the failure within thirty (30) days from the receipt of such notice. If the parties disagree as to whether the Company had just cause to terminate the Employee’s employment, the dispute will be submitted to binding arbitration pursuant to Section 7.10 below. 3.5. Definition of Disabled. As used herein, “Disabled” shall mean a mental or physical impairment which, in the reasonable opinion of a qualified doctor selected by mutual agreement of the Company and Employee acting reasonably, renders Employee unable, with reasonable accommodation, to perform with reasonable diligence the essential functions and duties of Employee on a full-time basis in accordance with the terms of this Agreement, which inability continues for a period of not less than 180 consecutive days. The providing of service to the Company for up to two (2) three (3) day periods during the one hundred and eighty (180) day period of disability will not affect the determination as to whether Employee is Disabled and will not restart the one hundred and eighty (180) day period of disability. If any dispute arises between the parties as to whether Employee is Disabled, Employee will submit to an examination by a physician selected by the mutual agreement of the Company and Employee acting reasonably, at the Company’s expense. The decision of the physician will be certified in writing to the Company, and will be sent by the Physician to Employee or Employee’s legally authorized representative, and will be conclusive for the purposes of determining whether Employee is Disabled. If Employee fails to submit to a medical examination within twenty (20) days after the Company’s request, Employee will be deemed to have voluntarily terminated his or her employment. 3.6. Return of Materials; Confidential Information. In connection with Employee’s separation from employment for any reason, Employee shall return any and all physical property belonging to the Company, and all material of whatever type containing “Confidential Information” as defined in Section 5.2 below, including, but not limited to, any and all documents, whether in 9 paper or electronic form, which contain Confidential Information, any customer information, production information, manufacturing-related information, pricing information, files, memoranda, reports, pass codes/access cards, training or other reference manuals, Company vehicle, telephone, gas cards or other Company credit cards, keys, computers, laptops, including any computer disks, software, facsimile machines, memory devices, printers, telephones, pagers or the like. 3.7. Delivery of Release. Within ten (10) working days after termination of Employee’s employment, and as a condition for receipt of payments set forth in Section 3.3(b)(i)(B), 3.3(b)(iii), and 4.1(a), the Company shall provide to Employee, or Employee’s legal representative, a form of written release, which form shall be satisfactory to the Company and generally consistent with the form of release used by the Company prior to such termination of employment (the “Release”) and which shall provide a full release of all claims against the Company and its corporate affiliates, except where Employee has been named as a defendant in a legal action arising out of the performance of Employee’s responsibilities in which case the Release will exempt any claims which Employee or his or her legal representative or estate may have for indemnity by the Company with respect to any such legal action. As a condition to the obligation of the Company to make the payments provided for in such Sections Employee, or Employee’s legal representative, shall execute and deliver the Release to the Company within the time periods provided for in said release. ARTICLE 4 CHANGE OF CONTROL 4.1. Effect of Change of Control. In the event of a Change of Control of EFI during the term of this Agreement, or any renewal of this Agreement the following provisions shall apply: (a) If upon the Change of Control (i) Employee is not retained by EFI or its successor (whether direct or indirect, by purchase of assets, merger, consolidation, exchange of securities, amalgamation, arrangement or otherwise) to all or substantially all of the business and/or assets of EFI (“Successor”) on the same terms and conditions as set out in this Agreement and in circumstances that would not constitute Good Reason (where Good Reason is determined by reference to Employee’s employment status prior to the Change of Control and prior to any other event that could constitute Good Reason); and/or (ii) any such Successor does not, by agreement in form and substance satisfactory to Employee, expressly assume and agree to perform this Agreement in the same manner and to the same extent that EFI would be required to perform it if no such succession had taken place, 10 then Employee shall be deemed to be terminated without just cause upon such Change of Control and shall be entitled to the compensation and all other rights specified in Article 3 in the same amount and on the same terms as if terminated without just cause as set out therein, subject to the additional rights set out in paragraph (c) below; (b) All rights of Employee in this Agreement, including without limitation all rights to severance and other rights upon a termination with or without cause, with or without Good Reason, upon a disability or upon death under Article 3 of this Agreement shall continue after a Change of Control in the same manner as before the Change of Control, subject to the additional rights set out in paragraph (c) below; (c) if, (i) there is a deemed termination without cause under Section 4.1(a); or (ii) within twelve (12) months following the effective date of the Change of Control, EFI, or its successor, terminates the employment of Employee without just cause or by reason of Disability, or Employee terminates his or her employment under this Agreement for Good Reason, then, in addition to the other rights Employee has under this Agreement, and notwithstanding any other provision in this Agreement, all of the stock options previously granted to Employee that have neither vested nor expired will automatically vest and become immediately exercisable, any period of restriction and other restrictions imposed on all RSUs shall lapse, and all RSUs shall be immediately settled and payable, and all other securities awarded shall vest and/or accelerate in accordance with Article 16 of the EFI Omnibus Equity Incentive Plan or the comparable provisions of any other equity incentive plan under which such securities may have been issued. Employee will have ninety (90) days from the effective date of the termination of Employee’s employment to exercise any stock options which had vested as of the effective date of termination and thereafter Employee’s stock options will expire and Employee will have no further right to exercise the stock options. 4.2. Definitions of Change of Control and Good Reason. For the purposes of this Agreement, (a) “Change of Control” will mean the happening of any of the following events: (i) any transaction at any time and by whatever means pursuant to which (A) EFI goes out of existence by any means, except for any corporate transaction or reorganization in which the proportionate voting power among holders of securities of the entity resulting from such corporate transaction or reorganization is substantially the same as the proportionate voting power of such holders of EFI voting securities immediately prior to such corporate transaction or reorganization 11 or (B) any Person (as defined in the Securities Act (Ontario)) or any group of two or more Persons acting jointly or in concert (other than EFI, a wholly-owned Subsidiary of EFI, an employee benefit plan of EFI or of any of its wholly-owned Subsidiaries (as defined in the Securities Act (Ontario)), including the trustee of any such plan acting as trustee) hereafter acquires the direct or indirect “beneficial ownership” (as defined by the Business Corporations Act (Ontario)) of, or acquires the right to exercise control or direction over, securities of EFI representing 50% or more of EFI’s then issued and outstanding securities in any manner whatsoever, including, without limitation, as a result of a take-over bid, an exchange of securities, an amalgamation of EFI with any other entity, an arrangement, a capital reorganization or any other business combination or reorganization; (ii) the sale, assignment or other transfer of all or substantially all of the assets of EFI in one or a series of transactions, whether or not related, to a Person or any group of two or more Persons acting jointly or in concert, other than a wholly- owned Subsidiary of EFI; (iii) the dissolution or liquidation of EFI except in connection with the distribution of assets of EFI to one or more Persons which were wholly-owned Subsidiaries of EFI immediately prior to such event; (iv) the occurrence of a transaction requiring approval of EFI’s shareholders whereby EFI is acquired through consolidation, merger, exchange of securities, purchase of assets, amalgamation, arrangement or otherwise by any other Person (other than a short form amalgamation or exchange of securities with a wholly-owned Subsidiary of EFI); (v) a majority of the members of the Board of Directors of EFI are replaced or changed as a result of or in connection with any: (A) take-over bid, consolidation, merger, exchange of securities, amalgamation, arrangement, capital reorganization or any other business combination or reorganization involving or relating to EFI; (B) sale, assignment or other transfer of all or substantially all of the assets of EFI in one or a series of transactions, or any purchase of assets; or (C) dissolution or liquidation of EFI; (vi) during any two-year period, a majority of the members of the Board of Directors of EFI serving at the date of this Agreement is replaced by directors who are not nominated and approved by the Board of Directors of EFI; (vii) an event set forth in (i), (ii), (iii), (iv), (v) or (vi) has occurred with respect to EFRI or any of its direct or indirect parent companies, in which case the term “EFI” in those paragraphs will be read to mean “EFRI or such parent company” 12 is: and the phrase “wholly-owned Subsidiary(ies)” will be read to mean “Affiliate(s) or wholly-owned Subsidiary(ies)”; or (viii) the Board of Directors of EFI passes a resolution to the effect that, an event set forth in (i), (ii), (iii), (iv), (v), (vi) or (vii) above has occurred. (b) “Good Reason” means, without the written agreement of Employee, there (i) a material reduction or diminution in the level of responsibility, or office of Employee, provided that before any claim of material reduction or diminution of responsibility may be relied upon by Employee, Employee must have provided written notice to Employee’s supervisor and the EFI’s Board of Directors of the alleged material reduction or diminution of responsibility and have given EFI at least thirty (30) calendar days within which to cure the alleged material reduction or diminution of responsibility; (ii) a reduction in the Employee’s Base Salary, Target Cash Bonus Percentage or Target Equity Award Percentage; or (iii) a proposed, forced relocation of Employee to another geographic location greater than fifty (50) miles from Employee’s office location at the time a move is requested after a Change of Control. ARTICLE 5 CONFIDENTIALITY 5.1. Position of Trust and Confidence. Employee acknowledges that in the course of discharging his or her responsibilities, he or she will occupy a position of trust and confidence with respect to the affairs and business of the Company and its customers and clients, and that he or she will have access to and be entrusted with detailed confidential information concerning the present and contemplated mining and exploration projects, prospects, and opportunities of the Company. Employee acknowledges that the disclosure of any such confidential information to the competitors of the Company or to the general public would be highly detrimental to the best interests of the Company. Employee further acknowledges and agrees that the right to maintain such detailed confidential information constitutes a proprietary right which the Company is entitled to protect. 5.2. Definition of Confidential Information. In this Agreement, “Confidential Information” means any information disclosed by or on behalf of the Company to Employee or developed by Employee in the performance of his or her responsibilities at any time before or after the execution of this Agreement, and includes any information, documents, or other materials (including, without limitation, any drawings, notes, data, reports, photographs, audio and/or video 13 recordings, samples and the like) relating to the business or affairs of the Company or its respective customers, clients or suppliers that is confidential or proprietary, whether or not such information: (i) is reduced to writing; (ii) was created or originated by an employee; or (iii) is designated or marked as “Confidential” or “Proprietary” or some other designation or marking. The Confidential Information includes, but is not limited to, the following categories of information relating to the Company: (a) information concerning the present and contemplated mining, milling, processing and exploration projects, prospects and opportunities, including joint venture projects, of the Company; (b) information concerning the application for permitting and eventual development or construction of the Company’s properties, the status of regulatory and environmental matters, the compliance status with respect to licenses, permits, laws and regulations, property and title matters and legal and litigation matters; (c) information of a technical nature such as ideas, discoveries, inventions, improvements, trade secrets, now-how, manufacturing processes, specifications, writings and other works of authorship; (d) financial and business information such as the Company’s business and strategic plans, earnings, assets, debts, prices, pricing structure, volume of purchases or sales, production, revenue and expense projections, historical financial statements, financial projections and budgets, historical and projected sales, capital spending budgets and plans, or other financial data whether related to the Company’s business generally, or to particular products, services, geographic areas, or time periods; (e) supply and service information such as goods and services suppliers’ names or addresses, terms of supply or service contracts of particular transactions, or related information about potential suppliers to the extent that such information is not generally known to the public, and to the extent that the combination of suppliers or use of a particular supplier, although generally known or available, yields advantages to the Company, the details of which are not generally known; (f) marketing information, such as details about ongoing or proposed marketing programs or agreements by or on behalf of the Company, sales forecasts or results of marketing efforts or information about impending transactions; 14 (g) personnel information relating to employees, contractors, or agents, such as personal histories, compensation or other terms of employment or engagement, actual or proposed promotions, hirings, resignations, disciplinary actions, terminations or reasons therefor, training methods, performance, or other employee information; (h) customer information, such as any compilation of past, existing or prospective customer’s names, addresses, backgrounds, requirements, records of purchases and prices, proposals or agreements between customers and the Company, status of customer accounts or credit, or related information about actual or prospective customers; (i) computer software of any type or form and in any stage of actual or anticipated development, including but not limited to, programs and program modules, routines and subroutines, procedures, algorithms, design concepts, design specifications (design notes, annotations, documentation, float charts, coding sheets, and the like), source codes, object code and load modules, programming, program patches and system designs; and (j) all information which becomes known to Employee as a result of Employee’s employment by the Company, which Employee acting reasonably, believes or ought to believe is confidential or proprietary information from its nature and from the circumstances surrounding its disclosure to Employee. 5.3. Non-Disclosure. Employee, both during his or her employment and for a period of five (5) years after the termination of his or her employment irrespective of the time, manner or cause of termination, will: (a) retain in confidence all of the Confidential Information; (b) refrain from disclosing to any person including, but not limited to, customers and suppliers of the Company, any of the Confidential Information except for the purpose of carrying out Employee’s responsibilities with the Company, and (c) refrain from directly or indirectly using or attempting to use such Confidential Information in any way, except for the purpose of carrying out Employee’s responsibilities with the Company. Employee shall deliver promptly to the Company, at the termination of Employee’s employment, or at any other time at the Company’s request, without retaining any copies, all documents and other material in Employee’s possession relating, directly or indirectly, to any Confidential Information. It is understood that should Employee be subject to subpoena or other legal process to seek the disclosure of such Confidential Information, Employee will advise the Company of such process 15 and provide the Company with the necessary information to seek to protect the Confidential Information. 5.4. Whistleblower Laws. The foregoing obligations of confidentiality set out in this Article 5 are subject to applicable whistleblower laws, which protect Employee’s right to provide information to governmental and regulatory authorities, including communications with the U.S. Securities and Exchange Commission about possible securities law violations. Notwithstanding any other provision in this Agreement, Employee is not required to seek the Company’s permission or notify the Company of any communications made in compliance with applicable whistleblower laws, and the Company will not consider any such communications to violate this Agreement or any other agreement between Employer and the Company or any Company policy by which Employee is bound. ARTICLE 6 NON-SOLICITATION 6.1. Non-Solicitation. Employee agrees that during the period (the “Non-Solicitation Period”) commencing on the date of this Agreement and ending twelve (12) months after the effective date of the termination of Employee’s employment irrespective of the time, manner or cause of termination, Employee will not, either individually or in partnership or jointly or in conjunction with any other person, entity or organization, as principal, agent, consultant, contractor, employer, employee or in any other manner, directly or indirectly: (a) solicit business from any customer, client or business relation of the Company, or prospective customer, client or business relation that the Company was actively soliciting, whether or not Employee had direct contact with such customer, client or business relation, for the benefit or on behalf of any person, firm or corporation operating a business which competes with the Company, or attempt to direct any such customer, client or business relation away from the Company or to discontinue or alter any one or more of their relationships with the Company; or (b) hire or offer to hire or entice away or in any other manner persuade or attempt to persuade any officer, employee, consultant, independent contractor, agent, licensee, supplier, or business relation of the Company to discontinue or alter any one of their relationships with the Company. 6.2. Remedies for Breach of Restrictive Covenants. Employee acknowledges that in connection with Employee’s employment he or she will receive or will become eligible to receive substantial benefits and compensation. Employee acknowledges that Employee’s employment by the Company and all compensation and benefits from such employment will be conferred by the Company upon Employee only because and on the condition of Employee’s willingness to commit Employee’s best efforts and loyalty to the Company, including protecting the Company’s confidential information and abiding by the non-solicitation covenants contained in this Agreement. 16 Employee understands that his obligations set out in Article 5 and this Article 6 will not unduly restrict or curtail Employee’s legitimate efforts to earn a livelihood following any termination of his or her employment with the Company. Employee agrees that the restrictions contained in Article 5 and this Article 6 are reasonable and valid and all defenses to the strict enforcement of these restrictions by the Company are waived by Employee. Employee further acknowledges that a breach or threatened breach by Employee of any of the provisions contained in Article 5 or this Article 6 would cause the Company irreparable harm which could not be adequately compensated in damages alone. Employee further acknowledges that it is essential to the effective enforcement of this Agreement that, in addition to any other remedies to which the Company may be entitled at law or in equity or otherwise, the Company will be entitled to seek and obtain, in a summary manner, from any Court having jurisdiction, interim, interlocutory, and permanent injunctive relief, specific performance and other equitable remedies, without bond or other security being required. In addition to any other remedies to which the Company may be entitled at law or in equity or otherwise, in the event of a breach of any of the covenants or other obligations contained in this Agreement, the Company will be entitled to an accounting and repayment of all profits, compensation, royalties, commissions, remuneration or benefits which Employee directly or indirectly, has realized or may realize relating to, arising out of, or in connection with any such breach. Should a court of competent jurisdiction declare any of the covenants set forth in Article 5 or this Article 6 unenforceable, the court shall be empowered to modify and reform such covenants so as to provide relief reasonably necessary to protect the interests of the Company and Employee and to award injunctive relief, or damages, or both, to which the Company may be entitled. ARTICLE 7 GENERAL PROVISIONS 7.1. Governing Law. This Agreement shall be governed by and construed in accordance with the laws of the state of Colorado. 7.2. Assignability. This Agreement is personal to Employee and without the prior written consent of the Company shall not be assignable by Employee other than by will or the laws of descent and distribution. This Agreement shall inure to the benefit of and be enforceable by Employee’s legal representatives and heirs. This Agreement shall also inure to the benefit of and be binding upon the Company and its successors and assigns. 7.3. Withholding. The Company may withhold from any amounts payable under this Agreement such federal, state or local taxes as shall be required to be withheld pursuant to any applicable law or regulation. 7.4. Entire Agreement; Amendment. This Agreement constitutes the entire agreement and understanding between Employee and the Company with respect to the subject matter hereof and, except as otherwise expressly provided herein, supersedes any prior agreements or 17 understandings, whether written or oral, with respect to the subject matter hereof, including without limitation all employment, severance or change of control agreements previously entered into between Employee and the Company or Uranerz Energy Corporation. Except as may be otherwise provided herein, this Agreement may not be amended or modified except by subsequent written agreement executed by both parties hereto. 7.5. Section 409A. This Agreement is intended to comply with Section 409Ato the extent Section 409A is applicable to this Agreement. Notwithstanding any other provision of this Agreement to the contrary, this Agreement shall be interpreted, operated and administered by the Company in a manner consistent with such intention and to avoid the pre-distribution inclusion in income of amounts deferred under this Agreement and the imposition of any additional tax or interest with respect thereto. Notwithstanding any other provision of this Agreement to the contrary, to the extent that any payment under this Agreement constitutes “nonqualified deferred compensation” under Section 409A, the following shall apply to the extent Section 409A is applicable to such payment: (a) Any payable that is triggered upon the Employee’s termination of employment shall be paid only if such termination of employment constitutes a “separation from service” under Section 409A; and (b) All expenses or other reimbursements paid pursuant to this Agreement that are taxable income to Employee shall be paid no later than the end of the calendar year next following the calendar year in which Employee incurs such expense. With regard to any provision herein that provides for reimbursement of costs and expenses or in-kind benefits, except as permitted by Section 409A, (a) the right to reimbursement or in-kind benefits shall not be subject to liquidation or exchange for another benefit, (b) the amount of expenses eligible for reimbursement, or in-kind benefits, provided during any taxable year shall not affect the expenses eligible for reimbursement, or in-kind benefits to be provided, in any other taxable year; and (c) such payments shall be made on or before the last day of Employee’s taxable year following the taxable year in which the expense occurred. For purposes of Section 409A, Employee’s right to receive installment payments of any severance amount, if applicable, shall be treated as a right to receive a series of separate and distinct payments. In the event that Employee is deemed on the date of termination to be a “specified employee” as defined in Section 409A, then with regard to any payment or the provision of any benefit that is subject to Section 409A and is payable on account of a separation from service (as defined in Section 409A), such payment or benefit shall be delayed for until the earlier of (a) the first business day of the seventh calendar month following such termination of employment, or (b) Employee’s death. Any payments delayed by reason of the prior sentence shall be paid in a single lump sum, without interest thereon, on the date indicated by the previous sentence and any remaining payments due under this Agreement shall be paid as otherwise provided herein. 18 7.6. Multiple Counterparts. This Agreement may be executed in multiple counterparts, each of which shall constitute an original, but all of which together shall constitute one Agreement. 7.7. Notices. Any notice provided for in this Agreement shall be deemed delivered upon deposit in the United States mails, registered or certified mail, addressed to the party to whom directed at the addresses set forth below or at such other addresses as may be substituted therefor by notice given hereunder. Notice given by any other means must be in writing and shall be deemed delivered only upon actual receipt. If to the Company: c/o Energy Fuels Resources (USA) Inc. 225 Union Blvd., Suite 600 Lakewood, CO 80228 Attention: President and Chief Executive Officer If to Employee: William Paul Goranson 5926 S. Jellison St., Apt. E Littleton, CO 80123 7.8. Waiver. The waiver of any term or condition of this Agreement, or any breach thereof, shall not be deemed to constitute the waiver of the same or any other term or condition of this Agreement, or any breach thereof. 7.9. Severability. In the event any provision of this Agreement is found to be unenforceable or invalid, such provision shall be severable from this Agreement and shall not affect the enforceability or validity of any other provision of this Agreement. If any provision of this Agreement is capable of two constructions, one of which would render the provision void and the other that would render the provision valid, then the provision shall have the construction that renders it valid.. 7.10. Arbitration of Disputes. Except for disputes and controversies arising under Articles 5 or 6 or involving equitable or injunctive relief, any dispute or controversy arising under or in connection with this Agreement shall be conducted in accordance with the Colorado Rules of Civil Procedure and, unless the parties mutually agree on an arbitrator shall be arbitrated by striking from a list of potential arbitrators provided by the Judicial Arbiter Group in Denver, Colorado. If the parties are unable to agree on an arbitrator, the arbitrator will be selected from a list of seven (7) potential arbitrators provided by the Judicial Arbiter Group in Denver. The Company and Employee will flip a coin to determine who will make the first strike. The parties will then alternate 19 striking from the list until there is one arbitrator remaining, who will be the selected arbitrator. Unless the parties otherwise agree and subject to the availability of the arbitrator, the arbitration will be heard within sixty (60) days following the appointment, and the decision of the arbitrator shall be binding on Employee and the Company and will not be subject to appeal. Judgment may be entered on the arbitrator’s award in any court having jurisdiction. 7.11. Currency. Except as expressly provided in this Agreement, all amounts in this Agreement are stated and shall be paid in United States dollars ($US). 7.12. Company’s Maximum Obligations. The compensation set out in this Agreement represents the Company’s maximum obligations, and other than as set out herein, Employee will not be entitled to any other compensation, rights or benefits in connection with Employee’s employment or the termination of Employee’s employment. 7.13. Full Payment; No Mitigation Obligation. The Company’s obligation to make the payments provided for in this Agreement and otherwise to perform its obligations hereunder shall be subject to any set-off, counterclaim, recoupment, defense or other claim, right or action which the Company may have against Employee. 20 IN WITNESS WHEREOF, the parties have executed this Agreement as of the Effective Date. ENERGY FUELS INC. By: /s/ Mark S. Chalmers Name: Mark S. Chalmers Title: President and Chief Executive Officer Date: February 14, 2018 ENERGY FUELS RESOURCES (USA) INC. By: /s/ Mark S. Chalmers Name: Mark S. Chalmers Title: President and Chief Executive Officer Date: February 14, 2018 By: /s/ William Paul Goranson Name: William Paul Goranson Title: Chief Operating Officer Date: February 14, 2018 21 EXHIBIT A JOB DESCRIPTION Working with the President and Chief Executive Officer, Employee shall be responsible for all aspects of the Company’s operations. The Chief Operating Officer focuses on the establishment and optimization of the day-to-day operations of the Company. Responsibilities include setting monthly production goals following input from sales and financial departments, and developing and monitoring production budgets. Working with and in accordance with directions from the President and Chief Executive Officer, the Chief Operating Officer’s essential duties and responsibilities include: • overseeing all of the Company’s operations • maintaining a culture of safety as a top priority • ensuring that environmental stewardship is a key component of the Company’s operating philosophy • ensuring all direct reports are informed of operational objectives and goals • monitoring production and operations costs against approved budgets • being responsible for overall costs of production to ensure that they are within Board- approved budgets • ensuring production is sufficient to meet current and long-term contracts and published guidance • ensuring the Company’s operations are in full compliance with all permits and • regulations setting operational and performance goals for each area that are aggressive, achievable and tied to the Company’s long term business plan • coordinating activities with legal and finance departments by maintaining open and regular communication • directing the Company’s Technical Services function • ensuring employees are motivated, rewarded appropriately, and have potential for advancement taking charge in high priority crises relating to operations • • establishing a culture of best practices for all Company operations Notwithstanding the foregoing, the President and Chief Executive Officer may from time to time or at any time retain or place any of the foregoing functions under his authority or under the authority of one or more of his other direct reports, provided that no such other direct report shall be responsible for the overall operations of the Company, and any such action on the part of the President and Chief Executive Officer shall not constitute a material reduction or diminution in the level of responsibility, or office of Employee. Employee shall report to the President and Chief Executive Officer of the Company. This position will be located in the Lakewood office with frequent travel as required. 22 Performance is to be based on Board-approved Performance Goals in accordance with the Company’s STIP and LTIP, which will be evaluated once per year. 23 EMPLOYMENT AGREEMENT THIS EMPLOYMENT AGREEMENT (“Agreement”) is effective as of the 1st day of February, 2018 (the “Effective Date”), by and between Energy Fuels Resources (USA) Inc., a Delaware corporation (“EFRI”), Energy Fuels Inc., an Ontario corporation (“EFI”) (EFRI and EFI are collectively referred to herein as the “Company”) and Mark S. Chalmers (“Employee”). In consideration of the agreements contained in this Agreement, and other good and valuable consideration, the receipt and sufficiency of which are hereby acknowledged, the Company and Employee hereby agree as follows: ARTICLE 1 EMPLOYMENT, REPORTING AND DUTIES 1.1. Employment. The Company hereby employs and engages the services of Employee to serve as President and Chief Executive Officer and Employee agrees to diligently and competently serve as and perform the functions of President and Chief Executive Officer for the compensation and benefits stated herein. Acopy of Employee’s current job description is attached hereto as Exhibit A, and Company and Employee agree and acknowledge that, subject to Section 4.2(b), Company retains the right to reasonably add to, or remove, duties and responsibilities set forth in that job description as business or other operating reasons may arise for changes to occur. It is understood that Employee will be appointed an officer of EFI and EFRI during the term of this Agreement, but that Employee’s direct employment relationship will be as an employee of EFRI. 1.2. Fulltime Service. Excluding any periods of vacation and sick leave to which Employee may be entitled, Employee agrees to devote Employee’s full time and energies to the responsibilities with the Company consistent with past practice and shall not, during the Term of this Agreement, be engaged in any business activity which would interfere with or prevent Employee from carrying out Employee’s duties under this Agreement. ARTICLE 2 COMPENSATION AND RELATED ITEMS 2.1. Compensation. As compensation and consideration for the services to be rendered by Employee under this Agreement, the Company agrees to pay Employee and Employee agrees to accept: (a) Base Salary and Benefits. A base salary (“Base Salary”) of $350,000 per annum, less required tax withholding, which shall be paid in accordance with the Company’s standard payroll practice. Employee’s Base Salary may be increased from time to time (but not decreased, including after any increase, without Employee’s written consent), at the discretion of 1 the Company, and after any such change, Employee’s new level of Base Salary shall be Employee’s Base Salary for purposes of this Agreement until the effective date of any subsequent change. Employee shall also receive benefits such as health insurance, vacation and other benefits consistent with the then applicable Company benefit plans to the same extent as other employees of the Company with similar position or level. Employee understands and agrees that, subject to Sections 2.1(b) and (c) below, Company’s benefit plans may, from time to time, be modified or eliminated at Company’s discretion. (b) Cash Bonus. A cash bonus opportunity (the “Cash Bonus”) during each calendar year with a target (the “Target Cash Bonus”) equal to fifty percent (50%) (the “Target Cash Bonus Percentage”) of Employees’ Base Salary for the year in which the cash bonus is paid, such cash bonus to be paid in accordance with the Company’s existing Short Term Incentive Plan, as such plan may be amended or replaced from time to time, or the equivalent (the “STIP”). Pursuant to the terms of the STIP, each annual Cash Bonus shall be payable based on the achievement of performance goals, and may be higher or lower than the Target Cash Bonus based on achievement of those goals. For each calendar year during the term of this Agreement, the Board (or the Compensation Committee) of EFI will determine and will establish in writing (i) the applicable STIP performance goals, which shall be reasonably achievable and if achieved would result in payment of the Target Cash Bonus, (iii) the percentage of annual Base Salary to be payable to Employee if some lesser or greater percentage of the annual STIP performance goals are achieved, and (iv) such other applicable terms and conditions of the STIP necessary to satisfy the requirements of Section 409A of the Internal Revenue Code of 1986, as amended (the "Code"); and (c) Equity Award. An equity award opportunity (the “Equity Award”) during each calendar year with a target value (the “Target Equity Award”) equal to one hundred percent (100%) (the “Target Equity Award Percentage”) of Employee’s Base Salary for the year in which the award is granted, such equity award to be awarded in accordance with the Company’s existing Long Term Incentive Plan, as such plan may be amended or replaced from time to time, or the equivalent (the “LTIP”). Pursuant to the terms of the LTIP, each annual equity award shall be made based on the achievement of performance goals, and may be higher or lower than the Target Equity Award based on achievement of those goals. For each calendar year during the term of this Agreement, the Board (or the Compensation Committee) of EFI will determine and will establish in writing (i) the applicable LTIP performance goals, which shall be reasonably achievable and if achieved would result in payment of the Target Equity Award, (iii) the percentage of annual Base Salary value to be awarded in equity to Employee if some lesser or greater percentage of the annual LTIP performance goals are achieved, and (iv) such other applicable terms and conditions of the LTIP necessary to satisfy the requirements of Section 409A of the Code. 2.2. Annual Medical. Employee shall have a comprehensive annual medical examination each calendar year of this Agreement. The Company will reimburse Employee for the cost of each such examination, provided that Employee requests such reimbursement and such reimbursement is made no later than the last day of the calendar year following the calendar year in which the 2 examination expense was incurred. Employee will promptly notify the Chairman of the Board of EFI (the “Chairman of the Board”) if the annual medical examination reveals any condition which, if untreated, is likely to interfere with Employee’s ability to perform the essential requirements of Employee’s position, and if requested by the Chairman of the Board, Employee will provide the details of the condition and the potential impact on his or her ability to perform the essential requirements of his or her position to enable the Chairman of the Board to determine how best to accommodate Employee and protect the critical business interests of the Company. 2.3. Expenses. The Company agrees that Employee shall be allowed reasonable and necessary business expenses in connection with the performance of Employee’s duties within the guidelines established by the Company as in effect at any time with respect to key employees (“Business Expenses”), including, but not limited to, reasonable and necessary expenses for food, travel, lodging, entertainment and other items in the promotion of the Company within such guidelines. The Company shall promptly reimburse Employee for all reasonable Business Expenses incurred by Employee upon Employee’s presentation to the Company of an itemized account thereof, together with receipts, vouchers, or other supporting documentation. 2.4. Vacation. Employee will be entitled to five weeks of vacation each year, in addition to the 10 paid holidays each year. Carry over from one year to the next will be as per the Company’s paid leave policy. 2.5. Work Away From Office. The Company recognizes that Employee may be completing his regular work away from the office each year during a period or periods of time aggregating up to two weeks per calendar year or as agreed to in writing by the Chairman of the Board. These periods of time will count as work time and will not count as vacation time or paid or unpaid leave. However, any travel and lodging for these periods of time will not be charged by Employee as a business expense unless pre-approved by the Chairman of the Board. The aggregate period of time explained here will be per calendar year, unless otherwise approved by the Board of Directors of EFI. 2.6. Vehicle. The Company will provide Employee the use of a vehicle for his unrestricted personal and work use, and will pay all reasonable maintenance and operating costs, while Employee is employed as President and Chief Executive Officer of the Company under this Agreement. The vehicle will be approved by the Chairman of the Board, will be new as of the Effective Date and will be suitable for both highway travel and off-road travel to access Company properties. The vehicle will be owned or leased by the Company, but Employee will have the option to acquire it in the circumstances set out in Section 3.3(b)(iv) below. 2.7. Outside Directorship. Employee shall be entitled to seek and maintain one non- executive, non-chair directorship with a publicly traded or privately owned company that does not compete directly or indirectly with the Company in any of the Company’s primary business lines. Employee shall not seek or maintain more than one such directorship or vary from any of the 3 foregoing requirements without the prior written approval of the Board of Directors of EFI. Such directorships exclude directorships on private family holding companies or on any company where Employee is requested by the Company to seek or maintain such a directorship. ARTICLE 3 TERMINATION 3.1. Term. Employee’s employment under this Agreement shall commence on the Effective Date and will end on the date (the “Initial Expiration Date”) that is the second anniversary of the Effective Date, unless terminated sooner under the provisions of this Article, or extended under the terms of this Section. If neither Company nor Employee provides written notice of intent not to renew this Agreement by ninety (90) days prior to the Initial Expiration Date, this Agreement shall be automatically renewed for twelve (12) additional months, and if neither Company nor Employee provides written notice of intent not to renew this Agreement prior to ninety (90) days before the end of such additional 12-month period, this Agreement shall continue to be automatically renewed for successive additional 12-month periods until such time either Company or Employee provides written notice of intent not to renew prior to ninety (90) days before the end of any such renewal period. 3.2. Termination of Employment. Except as may otherwise be provided herein, Employee’s employment under this Agreement may terminate upon the occurrence of: (a) Notice by Company. The termination date specified in a written notice of termination that is given by the Company to Employee; (b) Notice by Employee. Thirty (30) days after written notice of termination is given by Employee to the Company; (c) Employee’s becoming disabled; Death or Disability. Employee’s death or, at the Company’s option, upon (d) Deemed Termination Without Just Cause upon a Change of Control. A deemed termination without just cause under Section 4.1(a) upon the occurrence of a Change of Control; or (e) Notice Not to Renew. If the Company or Employee gives the other a notice not to renew this Agreement under Section 3.1, employment under this Agreement shall terminate at the close of business at the end of the Initial Expiration Date or at the end of the 12-month renewal period in which timely notice not to renew was given, as the case may be. A notice by the Company not to renew shall be considered a notice of termination, resulting in the Company terminating Employee’s employment under this Agreement. 4 Any notice of termination given by the Company to Employee under Section 3.2(a) or (e) above shall specify whether such termination is with or without just cause as defined in Section 3.4. Any notice of termination given by Employee to the Company under Section 3.2(b) above shall specify whether such termination is made with or without Good Reason as defined in Section 4.2(b). 3.3. Obligations of the Company Upon Termination. (a) With Just Cause/Without Good Reason. If the Company terminates Employee’s employment under this Agreement with just cause as defined in Section 3.4, or if Employee terminates his employment without Good Reason as defined in Section 4.2(b) (other than a voluntary retirement under Section 3.8(a)), in either case whether before or after a Change of Control as defined in Section 4.2(a), then Employee’s employment with the Company shall terminate without further obligation by the Company to Employee, other than payment of all accrued obligations (“Accrued Obligations”), including outstanding Base Salary, accrued vacation pay and any other cash benefits accrued up to and including the date of termination. That payment shall be made in one lump sum, less required tax withholding, within ten (10) working days after the effective date of such termination. Employee will have up to the earlier of: (A) ninety (90) days from the effective date of termination of Employee’s employment; or (B) the date on which the exercise period of the particular stock option expires, to exercise only that portion of the stock options previously granted to Employee that have not been exercised, but which have vested, and thereafter Employee’s stock options will expire and Employee will have no further right to exercise the stock options. Any stock options held by Employee that are not yet vested at the termination date immediately expire and are cancelled and forfeited to the Company on the termination date. Any Restricted Stock Units (“RSUs”) held by Employee that have vested on or before the termination date shall be paid (or the shares issuable thereunder issued) to Employee. Any RSUs held by Employee that are not vested on or before the termination date will be immediately cancelled and forfeited to the Company on the termination date. The rights of Employee upon termination in respect of any other awards granted to Employee under any of the Company’s equity compensation plans shall be as set forth in such plans or in the award agreement for any such awards, as applicable. Notwithstanding the foregoing, but subject to Section 3.8(a), on retirement, Employee will have up to the earlier of: (A) one hundred and eighty (180) days from the effective date of retirement; or (B) the date on which the exercise period of the particular stock option expires, to exercise only that portion of the stock options previously granted to Employee that have not been exercised, but which have vested, and thereafter Employee’s stock options will expire and Employee will have no further right to exercise the stock options. (b) With Good Reason/Without Just Cause/Disabled/Death. If Employee terminates Employee’s employment under this Agreement for Good Reason as defined in Section 4.2(b), or if the Company terminates Employee’s employment without just cause as defined in Section 3.4, or if the Company terminates Employee’s employment by reason of Employee becoming Disabled as defined in Section 3.5, or if Employee dies (in which case the date of 5 Employee’s death shall be considered his or her termination date), in any case whether before or after a Change of Control as defined in Section 4.2(a), or if there is a deemed termination without just cause upon a Change of Control as contemplated by Section 4.1(a), then Employee’s employment with the Company shall terminate, as of the effective date of the termination, and in lieu of any other severance benefit that would otherwise be payable to Employee: (i) the Company shall pay the following amounts to Employee (or, in the case of termination by reason of Employee becoming Disabled or upon the death of Employee, to Employee’s legal representative or estate as applicable) after the effective date of such termination, or in a manner and at such later time as specified by Employee (or Employee’s legal representative), and agreed to by the Company, subject to being in compliance with Section 409A of the Code: (A) all Accrued Obligations, less required tax withholding, up to and including the date of termination, to be paid on the date of termination of employment, or within no more than five (5) working days thereafter, and the Company will reimburse Employee for all proper expenses incurred by Employee in discharging his responsibilities to the Company prior to the effective date of termination of Employee’s employment in accordance with Section 2.3 above; and (B) an amount in cash equal to two and one half (2.5) (the “Severance Factor”) times the sum of Employee’s Base Salary, Target Cash Bonus and Target Equity Award for the full year in which the Date of Termination occurs, less required tax withholding, such amount to be paid within thirty (30) calendar days after the date Employee signs the Release contemplated by Section 3.7; (ii) Employee or Employee’s legal representative will have up to the earlier of: (A) ninety (90) days from the effective date of termination of Employee’s employment for all cases other than the death of Employee and twelve (12) months from the effective date of termination of Employee’s employment in the case of death of Employee; or (B) the date on which the exercise period of the particular stock option expires, to exercise only that portion of the stock options previously granted to Employee that have not been exercised, but which have vested, and thereafter Employee’s stock options will expire and Employee or his or her legal representative will have no further right to exercise the stock options. Subject to Section 4.1(c), any stock options held by Employee that are not yet vested at the termination date immediately expire and are cancelled and forfeited to the Company 6 on the termination date. Any RSUs held by Employee that have vested on or before the termination date shall be paid (or the shares issuable thereunder issued) to Employee or his or her legal representative or estate as applicable. Subject to Section 4.1(c), any RSUs held by Employee that are not vested on or before the termination date will be immediately cancelled and forfeited to the Company on the termination date. Subject to Section 4.1(c), the rights of Employee or his or her legal representative or estate as applicable upon termination in respect of any other awards granted to Employee under any of the Company’s equity compensation plans shall be as set forth in such plans or in the award agreement for any such awards, as applicable; (iii) Upon termination, the Company or its Successor (as defined in Section 4.1(a)), agrees to reimburse Employee the full cost of the COBRA continuation rate charged for employee and dependent coverage, through the EFRI Health and Welfare Plan on a monthly basis, for a period of months equal to twelve times the Severance Factor (the “Coverage Period”), beyond Employee’s termination month. Employee and his or her dependents may, at their choosing, enroll in the COBRA continuation plan through EFRI for the first eighteen months following Employee’s termination month or, if they choose, they may enroll in a separate plan of their choosing, by using the reimbursement to enroll in medical and prescription insurance of their choosing. Reimbursement at the rate described herein will continue for the Coverage Period beyond Employee’s termination month, but beginning with the nineteenth month, Employee and his or her dependents will need to obtain coverage from a different source than the COBRAcontinuation plan through EFRI. The reimbursement will be to Employee and his or her dependents directly, and will be grossed up so that there is no negative tax impact to the Employee or his or dependents for coverage of the premiums charged by the insurance carriers for the COBRA continuation coverage for the current month of reimbursement. The reimbursed cost of COBRA coverage will be indexed annually, and will match the rate charged for any month of coverage available by the insurance carrier for Medical, Dental, and Optical coverage through EFRI for employee and spouse coverage. Both Employee and his or her dependents, will have the option of purchasing a medical plan separate from the plan offered by EFRI; and (iv) At the sole option of Employee, Employee may purchase the vehicle contemplated by Section 2.5 above at then fair market value, as reasonably determined by the Company. If the Company owns the vehicle, the Company will transfer ownership of the vehicle to Employee at such value, or if the vehicle is leased by the Company, the Company will exercise the option to buy-out the lease and will transfer ownership of the vehicle to Employee at such value. In any case, 7 Employee will be responsible for any taxable benefit associated with the transfer of ownership of the vehicle to Employee, which the Company may deduct from the amounts payable to Employee under this Section 3.3(b). (v) Nothing herein shall preclude the Company from granting additional severance benefits to Employee upon termination of employment. Notwithstanding the foregoing, in the case of Disability, any Base Salary payable to Employee during the one hundred and eighty (180) day period of disability will be reduced by the amount of any disability benefits Employee receives or is entitled to receive as a result of any disability insurance policies for which the Company has paid the premiums. (c) Section 280G. Notwithstanding any other provisions of this Agreement, or any other plan, arrangement or agreement to the contrary, if any of the payments or benefits provided or to be provided by the Company or its affiliates to Employee or for Employee’s benefit pursuant to the terms of this Agreement or otherwise (“Covered Payments”) constitute “parachute payments” within the meaning of Section 280G of the Code and would, but for this Section 3.3(c) be subject to the excise tax imposed under Section 4999 of the Code (or any successor provision thereto) or any similar tax imposed by state or local law or any interest or penalties with respect to such taxes (collectively, the “Excise Tax”), then the following shall apply: (i) If the Covered Payments, reduced by the sum of (1) the Excise Tax and (2) the total of the Federal, state, and local income and employment taxes payable by Employee on the amount of the Covered Payments which are in excess of three times Employee’s “base amount” within the meaning of Section 280(G) of the Code less one dollar (the “Threshold Amount”), are greater than or equal to the Threshold Amount, Employee shall be entitled to the full benefits payable under this Agreement; and (ii) If the Threshold Amount is less than (1) the Covered Payments, but greater than (2) the Covered Payments reduced by the sum of (x) the Excise Tax and (y) the total of the Federal, state, and local income and employment taxes on the amount of the Covered Payments which are in excess of the Threshold Amount, then the Covered Payments shall be reduced (but not below zero) to the extent necessary so that the sum of all Covered Payments shall not exceed the Threshold Amount. In such event, the Covered Payments shall be reduced in the following order: (A) cash payments not subject to Section 409A; (B) cash payments subject to Section 409A; (C) equity-based payments and acceleration; and (D) non-cash forms of benefits. To the extent any payment is to be made over time (e.g., in installments, etc.), then the payments shall be reduced in reverse chronological order. 8 The determination as to which of the alternative provisions of Section 3.3(c)(ii) shall apply to Employee shall be made by a nationally recognized accounting firm selected by the Company (the “Accounting Firm”), which shall provide detailed supporting calculations both to the Company and Employee within 15 business days of the date of termination, if applicable, or at such earlier time as is reasonably requested by the Company or Employee. For purposes of determining which of the alternative provisions of Section 3.3(c)(ii) shall apply, Employee shall be deemed to pay Federal income taxes at the highest marginal rate of Federal income taxation applicable to individuals for the calendar year in which the determination is to be made, and state and local income taxes at the highest marginal rates of individual taxation in the state and locality of Employee’s residence on the date of termination, net of the maximum reduction in Federal income taxes which could be obtained from deduction of such state and local taxes. Any determination by the Accounting Firm shall be binding upon the Company and Employee. 3.4. Definition of Just Cause. As used in this Agreement, the term “just cause” will mean any one or more of the following events: (a) theft, fraud, dishonesty, or misappropriation by Employee involving the property, business or affairs of the Company or the discharge of Employee’s responsibilities or the exercise of his or her authority; (b) willful misconduct or the willful failure by Employee to properly discharge his or her responsibilities or to adhere to the policies of the Company (c) Employee’s gross negligence in the discharge of his or her responsibilities or involving the property, business or affairs of the Company to the material detriment of the Company; (d) Employee’s conviction of a criminal or other statutory offence that constitutes a felony or which has a potential sentence of imprisonment greater than six (6) months or Employee’s conviction of a criminal or other statutory offence involving, in the sole discretion of the Board of Directors of EFI, moral turpitude; (e) (f) or 6 below; Employee’s material breach of a fiduciary duty owed to the Company; any material breach by Employee of the covenants contained in Articles 5 (g) Employee’s unreasonable refusal to follow the lawful written direction of the Board of Directors of EFI on any material matter; (h) any conduct of Employee which, in the reasonable opinion of the Board of Directors of EFI, is materially detrimental or embarrassing to the Company; or 9 (i) any other conduct by Employee that would constitute “just cause” as that term is defined at law. The Company must provide written notice to Employee prior to termination for just cause pursuant to Section 3.4 (c), (f), (g), (h), or (i) and provide Employee the opportunity to correct and cure the failure within thirty (30) days from the receipt of such notice. If the parties disagree as to whether the Company had just cause to terminate the Employee’s employment, the dispute will be submitted to binding arbitration pursuant to Section 7.9 below. 3.5. Definition of Disabled. As used herein, “Disabled” shall mean a mental or physical impairment which, in the reasonable opinion of a qualified doctor selected by mutual agreement of the Company and Employee acting reasonably, renders Employee unable, with reasonable accommodation, to perform with reasonable diligence the essential functions and duties of Employee on a full-time basis in accordance with the terms of this Agreement, which inability continues for a period of not less than 180 consecutive days. The providing of service to the Company for up to two (2) three (3) day periods during the one hundred and eighty (180) day period of disability will not affect the determination as to whether Employee is Disabled and will not restart the one hundred and eighty (180) day period of disability. If any dispute arises between the parties as to whether Employee is Disabled, Employee will submit to an examination by a physician selected by the mutual agreement of the Company and Employee acting reasonably, at the Company’s expense. The decision of the physician will be certified in writing to the Company, and will be sent by the Physician to Employee or Employee’s legally authorized representative, and will be conclusive for the purposes of determining whether Employee is Disabled. If Employee fails to submit to a medical examination within twenty (20) days after the Company’s request, Employee will be deemed to have voluntarily terminated his or her employment. 3.6. Return of Materials; Confidential Information. In connection with Employee’s separation from employment for any reason, Employee shall return any and all physical property belonging to the Company, and all material of whatever type containing “Confidential Information” as defined in Section 5.2 below, including, but not limited to, any and all documents, whether in paper or electronic form, which contain Confidential Information, any customer information, production information, manufacturing-related information, pricing information, files, memoranda, reports, pass codes/access cards, training or other reference manuals, Company vehicle (subject to Section 3.3(b)(iv)), telephone, gas cards or other Company credit cards, keys, computers, laptops, including any computer disks, software, facsimile machines, memory devices, printers, telephones, pagers or the like. 3.7. Delivery of Release. Within ten (10) working days after termination of Employee’s employment, and as a condition for receipt of payments set forth in Section 3.3(b)(i)(B), 3.3(b)(iii), 3.3(b)(iv), 3.8(a) and 4.1(a), the Company shall provide to Employee, or Employee’s legal representative, a form of written release, which form shall be satisfactory to the Company and 10 generally consistent with the form of release used by the Company prior to such termination of employment (the “Release”) and which shall provide a full release of all claims against the Company and its corporate affiliates, except where Employee has been named as a defendant in a legal action arising out of the performance of Employee’s responsibilities in which case the Release will exempt any claims which Employee or his or her legal representative or estate may have for indemnity by the Company with respect to any such legal action. As a condition to the obligation of the Company to make the payments provided for in such Sections Employee, or Employee’s legal representative, shall execute and deliver the Release to the Company within the time periods provided for in said release. 3.8. Retirement. (a) If Employee voluntarily retires from the Company at any time after the fifth anniversary of the Effective Date of this Agreement: (i) The provisions of Section 3.3(b)(i)A. will apply, and provided Employee has given the Company at least 6 months written notice of his retirement, the provisions of Sections 3.3(b)(iii) and 3.3(b)(iv) above will also apply, and the Company will pay the Employee the amounts and will take the actions specified in those Sections on the basis that the Employee’s retirement date shall be considered to be his termination date for purposes of those sections; and (ii) provided Employee has given the Company at least 6 months written notice of his retirement, all of the stock options previously granted to the Employee that have neither vested nor expired will automatically vest and become immediately exercisable, and will continue to be exercisable for a period of six months after the Employee’s date of retirement, any period of restriction and other restrictions imposed on all RSUs shall lapse, all RSUs shall be immediately settled and payable (or the shares issuable thereunder issued), and all other securities awarded under the EFI Omnibus Equity Incentive Plan or any other equity incentive plan shall vest and/ or accelerate effective as of the date of retirement. (b) The parties acknowledge that additional retirement and successor provisions may be addressed in the future if and when appropriate, and corresponding amendments may be made to this Agreement at that time by written agreement of the parties. 11 ARTICLE 4 CHANGE OF CONTROL 4.1. Effect of Change of Control. In the event of a Change of Control of EFI during the term of this Agreement, or any renewal of this Agreement the following provisions shall apply: (a) If upon the Change of Control (i) Employee is not retained by EFI or its successor (whether direct or indirect, by purchase of assets, merger, consolidation, exchange of securities, amalgamation, arrangement or otherwise) to all or substantially all of the business and/or assets of EFI (“Successor”) on the same terms and conditions as set out in this Agreement and in circumstances that would not constitute Good Reason (where Good Reason is determined by reference to Employee’s employment status prior to the Change of Control and prior to any other event that could constitute Good Reason); and/or (ii) any such Successor does not, by agreement in form and substance satisfactory to Employee, expressly assume and agree to perform this Agreement in the same manner and to the same extent that EFI would be required to perform it if no such succession had taken place, then Employee shall be deemed to be terminated without just cause upon such Change of Control and shall be entitled to the compensation and all other rights specified in Article 3 in the same amount and on the same terms as if terminated without just cause as set out therein, subject to the additional rights set out in paragraph (c) below; (b) All rights of Employee in this Agreement, including without limitation all rights to severance and other rights upon a termination with or without cause, with or without Good Reason, upon a disability or upon death under Article 3 of this Agreement shall continue after a Change of Control in the same manner as before the Change of Control, subject to the additional rights set out in paragraph (c) below; (c) if, (i) there is a deemed termination without cause under Section 4.1(a); or (ii) within twelve (12) months following the effective date of the Change of Control, EFI, or its successor, terminates the employment of Employee without just cause or by reason of Disability, or Employee terminates his or her employment under this Agreement for Good Reason, 12 then, in addition to the other rights Employee has under this Agreement, and notwithstanding any other provision in this Agreement, all of the stock options previously granted to Employee that have neither vested nor expired will automatically vest and become immediately exercisable, any period of restriction and other restrictions imposed on all RSUs shall lapse, and all RSUs shall be immediately settled and payable, and all other securities awarded shall vest and/or accelerate in accordance with Article 16 of the EFI Omnibus Equity Incentive Plan or the comparable provisions of any other equity incentive plan under which such securities may have been issued. Employee will have ninety (90) days from the effective date of the termination of Employee’s employment to exercise any stock options which had vested as of the effective date of termination and thereafter Employee’s stock options will expire and Employee will have no further right to exercise the stock options. 4.2. Definitions of Change of Control and Good Reason. For the purposes of this Agreement, (a) “Change of Control” will mean the happening of any of the following events: (i) any transaction at any time and by whatever means pursuant to which (A) EFI goes out of existence by any means, except for any corporate transaction or reorganization in which the proportionate voting power among holders of securities of the entity resulting from such corporate transaction or reorganization is substantially the same as the proportionate voting power of such holders of EFI voting securities immediately prior to such corporate transaction or reorganization or (B) any Person (as defined in the Securities Act (Ontario)) or any group of two or more Persons acting jointly or in concert (other than EFI, a wholly-owned Subsidiary of EFI, an employee benefit plan of EFI or of any of its wholly-owned Subsidiaries (as defined in the Securities Act (Ontario)), including the trustee of any such plan acting as trustee) hereafter acquires the direct or indirect “beneficial ownership” (as defined by the Business Corporations Act (Ontario)) of, or acquires the right to exercise control or direction over, securities of EFI representing 50% or more of EFI’s then issued and outstanding securities in any manner whatsoever, including, without limitation, as a result of a take-over bid, an exchange of securities, an amalgamation of EFI with any other entity, an arrangement, a capital reorganization or any other business combination or reorganization; (ii) the sale, assignment or other transfer of all or substantially all of the assets of EFI in one or a series of transactions, whether or not related, to a Person or any group of two or more Persons acting jointly or in concert, other than a wholly- owned Subsidiary of EFI; (iii) the dissolution or liquidation of EFI except in connection with the distribution of assets of EFI to one or more Persons which were wholly-owned Subsidiaries of EFI immediately prior to such event; 13 (iv) the occurrence of a transaction requiring approval of EFI’s shareholders whereby EFI is acquired through consolidation, merger, exchange of securities, purchase of assets, amalgamation, arrangement or otherwise by any other Person (other than a short form amalgamation or exchange of securities with a wholly-owned Subsidiary of EFI); (v) a majority of the members of the Board of Directors of EFI are replaced or changed as a result of or in connection with any: (A) take-over bid, consolidation, merger, exchange of securities, amalgamation, arrangement, capital reorganization or any other business combination or reorganization involving or relating to EFI; (B) sale, assignment or other transfer of all or substantially all of the assets of EFI in one or a series of transactions, or any purchase of assets; or (C) dissolution or liquidation of EFI; (vi) during any two-year period, a majority of the members of the Board of Directors of EFI serving at the date of this Agreement is replaced by directors who are not nominated and approved by the Board of Directors of EFI; (vii) an event set forth in (i), (ii), (iii), (iv), (v) or (vi) has occurred with respect to EFRI or any of its direct or indirect parent companies, in which case the term “EFI” in those paragraphs will be read to mean “EFRI or such parent company” and the phrase “wholly-owned Subsidiary(ies)” will be read to mean “Affiliate(s) or wholly-owned Subsidiary(ies)”; or (viii) the Board of Directors of EFI passes a resolution to the effect that, an event set forth in (i), (ii), (iii), (iv), (v), (vi) or (vii) above has occurred. (b) “Good Reason” means, without the written agreement of Employee, there (i) a material reduction or diminution in the level of responsibility, or office of Employee, provided that before any claim of material reduction or diminution of responsibility may be relied upon by Employee, Employee must have provided written notice to Employee’s supervisor and the EFI’s Board of Directors of the alleged material reduction or diminution of responsibility and have given EFI at least thirty (30) calendar days within which to cure the alleged material reduction or diminution of responsibility; (ii) a reduction in the Employee’s Base Salary, Target Cash Bonus Percentage or Target Equity Award Percentage; or (iii) a proposed, forced relocation of Employee to another geographic location greater than fifty (50) miles from Employee’s office location at the time a move is requested after a Change of Control. 14 is: ARTICLE 5 CONFIDENTIALITY 5.1. Position of Trust and Confidence. Employee acknowledges that in the course of discharging his or her responsibilities, he or she will occupy a position of trust and confidence with respect to the affairs and business of the Company and its customers and clients, and that he or she will have access to and be entrusted with detailed confidential information concerning the present and contemplated mining and exploration projects, prospects, and opportunities of the Company. Employee acknowledges that the disclosure of any such confidential information to the competitors of the Company or to the general public would be highly detrimental to the best interests of the Company. Employee further acknowledges and agrees that the right to maintain such detailed confidential information constitutes a proprietary right which the Company is entitled to protect. 5.2. Definition of Confidential Information. In this Agreement, “Confidential Information” means any information disclosed by or on behalf of the Company to Employee or developed by Employee in the performance of his or her responsibilities at any time before or after the execution of this Agreement, and includes any information, documents, or other materials (including, without limitation, any drawings, notes, data, reports, photographs, audio and/or video recordings, samples and the like) relating to the business or affairs of the Company or its respective customers, clients or suppliers that is confidential or proprietary, whether or not such information: (i) is reduced to writing; (ii) was created or originated by an employee; or (iii) is designated or marked as “Confidential” or “Proprietary” or some other designation or marking. The Confidential Information includes, but is not limited to, the following categories of information relating to the Company: (a) information concerning the present and contemplated mining, milling, processing and exploration projects, prospects and opportunities, including joint venture projects, of the Company; (b) information concerning the application for permitting and eventual development or construction of the Company’s properties, the status of regulatory and environmental matters, the compliance status with respect to licenses, permits, laws and regulations, property and title matters and legal and litigation matters; 15 (c) information of a technical nature such as ideas, discoveries, inventions, improvements, trade secrets, now-how, manufacturing processes, specifications, writings and other works of authorship; (d) financial and business information such as the Company’s business and strategic plans, earnings, assets, debts, prices, pricing structure, volume of purchases or sales, production, revenue and expense projections, historical financial statements, financial projections and budgets, historical and projected sales, capital spending budgets and plans, or other financial data whether related to the Company’s business generally, or to particular products, services, geographic areas, or time periods; (e) supply and service information such as goods and services suppliers’ names or addresses, terms of supply or service contracts of particular transactions, or related information about potential suppliers to the extent that such information is not generally known to the public, and to the extent that the combination of suppliers or use of a particular supplier, although generally known or available, yields advantages to the Company, the details of which are not generally known; (f) marketing information, such as details about ongoing or proposed marketing programs or agreements by or on behalf of the Company, sales forecasts or results of marketing efforts or information about impending transactions; (g) personnel information relating to employees, contractors, or agents, such as personal histories, compensation or other terms of employment or engagement, actual or proposed promotions, hirings, resignations, disciplinary actions, terminations or reasons therefor, training methods, performance, or other employee information; (h) customer information, such as any compilation of past, existing or prospective customer’s names, addresses, backgrounds, requirements, records of purchases and prices, proposals or agreements between customers and the Company, status of customer accounts or credit, or related information about actual or prospective customers; (i) computer software of any type or form and in any stage of actual or anticipated development, including but not limited to, programs and program modules, routines and subroutines, procedures, algorithms, design concepts, design specifications (design notes, annotations, documentation, float charts, coding sheets, and the like), source codes, object code and load modules, programming, program patches and system designs; and (j) all information which becomes known to Employee as a result of Employee’s employment by the Company, which Employee acting reasonably, believes or ought to believe is confidential or proprietary information from its nature and from the circumstances surrounding its disclosure to Employee. 16 5.3. Non-Disclosure. Employee, both during his or her employment and for a period of five (5) years after the termination of his or her employment irrespective of the time, manner or cause of termination, will: (a) retain in confidence all of the Confidential Information; (b) refrain from disclosing to any person including, but not limited to, customers and suppliers of the Company, any of the Confidential Information except for the purpose of carrying out Employee’s responsibilities with the Company, and (c) refrain from directly or indirectly using or attempting to use such Confidential Information in any way, except for the purpose of carrying out Employee’s responsibilities with the Company. Employee shall deliver promptly to the Company, at the termination of Employee’s employment, or at any other time at the Company’s request, without retaining any copies, all documents and other material in Employee’s possession relating, directly or indirectly, to any Confidential Information. It is understood that should Employee be subject to subpoena or other legal process to seek the disclosure of such Confidential Information, Employee will advise the Company of such process and provide the Company with the necessary information to seek to protect the Confidential Information. 5.4. Whistleblower Laws. The foregoing obligations of confidentiality set out in this Article 5 are subject to applicable whistleblower laws, which protect Employee’s right to provide information to governmental and regulatory authorities, including communications with the U.S. Securities and Exchange Commission about possible securities law violations. Notwithstanding any other provision in this Agreement, Employee is not required to seek the Company’s permission or notify the Company of any communications made in compliance with applicable whistleblower laws, and the Company will not consider any such communications to violate this Agreement or any other agreement between Employer and the Company or any Company policy by which Employee is bound. ARTICLE 6 NON-SOLICITATION 6.1. Non-Solicitation. Employee agrees that during the period (the “Non-Solicitation Period”) commencing on the date of this Agreement and ending twelve (12) months after the effective date of the termination of Employee’s employment irrespective of the time, manner or cause of termination, Employee will not, either individually or in partnership or jointly or in conjunction with any other person, entity or organization, as principal, agent, consultant, contractor, employer, employee or in any other manner, directly or indirectly: 17 (a) solicit business from any customer, client or business relation of the Company, or prospective customer, client or business relation that the Company was actively soliciting, whether or not Employee had direct contact with such customer, client or business relation, for the benefit or on behalf of any person, firm or corporation operating a business which competes with the Company, or attempt to direct any such customer, client or business relation away from the Company or to discontinue or alter any one or more of their relationships with the Company; or (b) hire or offer to hire or entice away or in any other manner persuade or attempt to persuade any officer, employee, consultant, independent contractor, agent, licensee, supplier, or business relation of the Company to discontinue or alter any one of their relationships with the Company. 6.2. Remedies for Breach of Restrictive Covenants. Employee acknowledges that in connection with Employee’s employment he or she will receive or will become eligible to receive substantial benefits and compensation. Employee acknowledges that Employee’s employment by the Company and all compensation and benefits from such employment will be conferred by the Company upon Employee only because and on the condition of Employee’s willingness to commit Employee’s best efforts and loyalty to the Company, including protecting the Company’s confidential information and abiding by the non-solicitation covenants contained in this Agreement. Employee understands that his obligations set out in Article 5 and this Article 6 will not unduly restrict or curtail Employee’s legitimate efforts to earn a livelihood following any termination of his or her employment with the Company. Employee agrees that the restrictions contained in Article 5 and this Article 6 are reasonable and valid and all defenses to the strict enforcement of these restrictions by the Company are waived by Employee. Employee further acknowledges that a breach or threatened breach by Employee of any of the provisions contained in Article 5 or this Article 6 would cause the Company irreparable harm which could not be adequately compensated in damages alone. Employee further acknowledges that it is essential to the effective enforcement of this Agreement that, in addition to any other remedies to which the Company may be entitled at law or in equity or otherwise, the Company will be entitled to seek and obtain, in a summary manner, from any Court having jurisdiction, interim, interlocutory, and permanent injunctive relief, specific performance and other equitable remedies, without bond or other security being required. In addition to any other remedies to which the Company may be entitled at law or in equity or otherwise, in the event of a breach of any of the covenants or other obligations contained in this Agreement, the Company will be entitled to an accounting and repayment of all profits, compensation, royalties, commissions, remuneration or benefits which Employee directly or indirectly, has realized or may realize relating to, arising out of, or in connection with any such breach. Should a court of competent jurisdiction declare any of the covenants set forth in Article 5 or this Article 6 unenforceable, the court shall be empowered to modify and reform such covenants so as to provide relief reasonably necessary to protect the interests of the Company and Employee and to award injunctive relief, or damages, or both, to which the Company may be entitled. 18 ARTICLE 7 GENERAL PROVISIONS 7.1. Governing Law. This Agreement shall be governed by and construed in accordance with the laws of the state of Colorado. 7.2. Assignability. This Agreement is personal to Employee and without the prior written consent of the Company shall not be assignable by Employee other than by will or the laws of descent and distribution. This Agreement shall inure to the benefit of and be enforceable by Employee’s legal representatives and heirs. This Agreement shall also inure to the benefit of and be binding upon the Company and its successors and assigns. 7.3. Withholding. The Company may withhold from any amounts payable under this Agreement such federal, state or local taxes as shall be required to be withheld pursuant to any applicable law or regulation. 7.4. Entire Agreement; Amendment. This Agreement constitutes the entire agreement and understanding between Employee and the Company with respect to the subject matter hereof and, except as otherwise expressly provided herein, supersedes any prior agreements or understandings, whether written or oral, with respect to the subject matter hereof, including without limitation all employment, severance or change of control agreements previously entered into between Employee and the Company. Except as may be otherwise provided herein, this Agreement may not be amended or modified except by subsequent written agreement executed by both parties hereto. 7.5. Section 409A. This Agreement is intended to comply with Section 409Ato the extent Section 409A is applicable to this Agreement. Notwithstanding any other provision of this Agreement to the contrary, this Agreement shall be interpreted, operated and administered by the Company in a manner consistent with such intention and to avoid the pre-distribution inclusion in income of amounts deferred under this Agreement and the imposition of any additional tax or interest with respect thereto. Notwithstanding any other provision of this Agreement to the contrary, to the extent that any payment under this Agreement constitutes “nonqualified deferred compensation” under Section 409A, the following shall apply to the extent Section 409A is applicable to such payment: (a) Any payable that is triggered upon the Employee’s termination of employment shall be paid only if such termination of employment constitutes a “separation from service” under Section 409A; and (b) All expenses or other reimbursements paid pursuant to this Agreement that are taxable income to Employee shall be paid no later than the end of the calendar year next following the calendar year in which Employee incurs such expense. With regard to any provision herein that 19 provides for reimbursement of costs and expenses or in-kind benefits, except as permitted by Section 409A, (a) the right to reimbursement or in-kind benefits shall not be subject to liquidation or exchange for another benefit, (b) the amount of expenses eligible for reimbursement, or in-kind benefits, provided during any taxable year shall not affect the expenses eligible for reimbursement, or in-kind benefits to be provided, in any other taxable year; and (c) such payments shall be made on or before the last day of Employee’s taxable year following the taxable year in which the expense occurred. For purposes of Section 409A, Employee’s right to receive installment payments of any severance amount, if applicable, shall be treated as a right to receive a series of separate and distinct payments. In the event that Employee is deemed on the date of termination to be a “specified employee” as defined in Section 409A, then with regard to any payment or the provision of any benefit that is subject to Section 409A and is payable on account of a separation from service (as defined in Section 409A), such payment or benefit shall be delayed for until the earlier of (a) the first business day of the seventh calendar month following such termination of employment, or (b) Employee’s death. Any payments delayed by reason of the prior sentence shall be paid in a single lump sum, without interest thereon, on the date indicated by the previous sentence and any remaining payments due under this Agreement shall be paid as otherwise provided herein. 7.6. Multiple Counterparts. This Agreement may be executed in multiple counterparts, each of which shall constitute an original, but all of which together shall constitute one Agreement. 7.7. Notices. Any notice provided for in this Agreement shall be deemed delivered upon deposit in the United States mails, registered or certified mail, addressed to the party to whom directed at the addresses set forth below or at such other addresses as may be substituted therefor by notice given hereunder. Notice given by any other means must be in writing and shall be deemed delivered only upon actual receipt. If to the Company: c/o Energy Fuels Resources (USA) Inc. 225 Union Blvd., Suite 600 Lakewood, CO 80228 Attention: Chairman of the Board of Energy Fuels Inc. 20 If to Employee: Mark S. Chalmers 13019 W. 73rd Place Arvada, CO 80005 7.8. Waiver. The waiver of any term or condition of this Agreement, or any breach thereof, shall not be deemed to constitute the waiver of the same or any other term or condition of this Agreement, or any breach thereof. 7.9. Severability. In the event any provision of this Agreement is found to be unenforceable or invalid, such provision shall be severable from this Agreement and shall not affect the enforceability or validity of any other provision of this Agreement. If any provision of this Agreement is capable of two constructions, one of which would render the provision void and the other that would render the provision valid, then the provision shall have the construction that renders it valid. 7.10. Arbitration of Disputes. Except for disputes and controversies arising under Articles 5 or 6 or involving equitable or injunctive relief, any dispute or controversy arising under or in connection with this Agreement shall be conducted in accordance with the Colorado Rules of Civil Procedure and, unless the parties mutually agree on an arbitrator shall be arbitrated by striking from a list of potential arbitrators provided by the Judicial Arbiter Group in Denver, Colorado. If the parties are unable to agree on an arbitrator, the arbitrator will be selected from a list of seven (7) potential arbitrators provided by the Judicial Arbiter Group in Denver. The Company and Employee will flip a coin to determine who will make the first strike. The parties will then alternate striking from the list until there is one arbitrator remaining, who will be the selected arbitrator. Unless the parties otherwise agree and subject to the availability of the arbitrator, the arbitration will be heard within sixty (60) days following the appointment, and the decision of the arbitrator shall be binding on Employee and the Company and will not be subject to appeal. Judgment may be entered on the arbitrator’s award in any court having jurisdiction. 7.11. Currency. Except as expressly provided in this Agreement, all amounts in this Agreement are stated and shall be paid in United States dollars ($US). 7.12. Company’s Maximum Obligations. The compensation set out in this Agreement represents the Company’s maximum obligations, and other than as set out herein, Employee will not be entitled to any other compensation, rights or benefits in connection with Employee’s employment or the termination of Employee’s employment. 7.13. Full Payment; No Mitigation Obligation. The Company’s obligation to make the payments provided for in this Agreement and otherwise to perform its obligations hereunder shall 21 be subject to any set-off, counterclaim, recoupment, defense or other claim, right or action which the Company may have against Employee. IN WITNESS WHEREOF, the parties have executed this Agreement as of the Effective Date. ENERGY FUELS INC. By: /s/ J. Birks Bovaird Name: J. Birks Bovaird Title: Chairman of the Board Date: February 1, 2018 ENERGY FUELS RESOURCES (USA) INC. By: /s/ David C. Frydenlund Name: David C. Frydenlund Title: Sr. Vice President, General Counsel and Corporate Secretary Date: February 1, 2018 /s/ Mark S. Chalmers By: Name: Mark S. Chalmers Title: President and Chief Executive Officer Date: February 1, 2018 22 EXHIBIT A JOB DESCRIPTION Employee will discharge the responsibilities and exercise the authority expected of a President and Chief Executive Officer of a public mining company. More specifically, in addition to exercising general control of and supervision over the Company’s affairs, the following are the responsibilities of the President and Chief Executive Officer: A. Foster a corporate culture that promotes ethical practices, encourages individual integrity and fulfills social responsibility; B. Maintain a positive and ethical work climate that is conducive to attracting, retaining and motivating a diverse group of top-quality employees at all levels; C. Develop and recommend to the Board, a long-term strategy and vision for the Company that leads to the creation of shareholder value; D. Develop and recommend to the Board, annual business plans and budgets that support the Company’s long term strategy; E. Determine the appropriate use of technology; F. Develop and recommend to the Board, the allocation of capital necessary to achieve the Company’s business plan; G. Ensure that the day-to-day business affairs of the Company are appropriately managed, including evaluation of the Company’s operating performance and initiating appropriate action where required; H. Consistently strive to achieve the Company’s financial and operating goals and objectives; I. J. Ensure fair presentation of the financial condition of the Company in continuous disclosure documents, and oversight and assessment of internal and disclosure controls of the Company; Ensure that the Company builds and maintains a strong positive relationship with its investors; K. Ensure that the Company achieves and maintains a competitive position within the industry; 23 L. Ensure that the Company builds and maintains a strong positive relationship with its employees; M. Ensure that the Company has an effective management team below the level of CEO and has an active plan for their development and succession; N. Formulate and oversee the implementation of major corporate policies; O. Ensure compliance with the Company’s Corporate Disclosure Policy, Environment, Health and Safety Policy and other policies; P. Build and maintain strong relationships with the corporate and public community; and Q. Ensure management support for Board Committees. Employee shall report to the Board of Directors of EFI. This position will be located in the Lakewood office with frequent travel as required. Performance is to be based on Board-approved Performance Goals pursuant to EFI’s STIP and LTIP, which will be evaluated once per year. 24 (USA) Inc. EXHIBIT 10.11 Energy Fuels Resources 225 Union Blvd. Suite 600 Lakewood, CO, US, 80228 303 974 2140 www.energyfuels.com THIS PROFESSIONAL SERVICES AGREEMENT is made as of the 2nd day of March, 2018 BETWEEN: ENERGY FUELS RESOURCES (USA) INC., a Delaware Corporation, having its offices at 225 Union Blvd., Suite 600, Lakewood, Colorado, United States of America 80228 (Hereinafter “EFRI”) OF THE FIRST PART -and- Daniel G. Zang, an accounting specialist (hereinafter “Contractor”). OF THE SECOND PART. WHEREAS EFRI wishes to enter into a professional services agreement with Contractor as a consultant to EFRI, by entering into this agreement (the “Agreement”), NOW THEREFORE in consideration of the mutual covenants and agreements hereinafter contained, the parties hereto agree as follows: 1. 2. 3. Services & Responsibilities. Contractor shall perform the services (the “Services”) as detailed in Exhibit “A” - “Scope of Services” which Exhibit shall be deemed a part hereof. Each change in the Services must be authorized in advance in writing by EFRI. Contractor shall not have the power and authority to sign any instruments that obligate or bind EFRI or any of its affiliates. Nothing contained in this Section 1 shall alter the status of Contractor as an independent contractor. Term of Agreement. The term of this Agreement shall commence on March 2, 2018 and shall continue until terminated in accordance with Section 9 hereof (the “Professional Services Period”). Compensation. As full consideration for performance hereunder, EFRI will pay Contractor according to Exhibit “B” - “Compensation for Services” which shall be deemed a part hereof. The 1 4. 5. 6. 7. 8. consideration set forth in this Section 3 shall be the sole consideration due Contractor for the Services rendered hereunder, and it is understood that EFRI will not withhold any amounts for payment of taxes from the compensation of Contractor hereunder. Contractor will not represent to be or hold himself out as an employee of EFRI or any of its affiliates, and Contractor acknowledges that he shall not have the right or entitlement in or to any of the equity compensation, bonus, pension, retirement, vacation or any other benefit programs now or hereafter available to EFRI’s regular employees. Contractor acknowledges his obligation to report and pay all federal, state and local taxes or assessments of any kind that a self- employed individual must pay. Contractor further covenants with EFRI that he will not at any time assert any claims against EFRI or any of its affiliates that he is entitled to any type of compensation as a statutory or common law employee of EFRI or any of its affiliates for any services provided during the term of this Agreement or any renewal thereof. Invoicing and Payment. The total compensation will be paid upon receipt of proper invoices by the Chief Financial Officer on or about the last day of each month, as agreed in writing between EFRI and Contractor as set out in Exhibit “B”. Properly documented expense reports shall be an integral part of the invoice. Also included as part of each invoice shall be a brief report outlining the activities and/ or the accomplishments achieved during the month. Stock Options and Restricted Stock Units.Your existing Energy Fuels Stock Options will continue to vest and remain exercisable, and your existing Restricted Stock Units will continue to vest, in both cases for the duration of the Professional Services Period. Compliance with Law and Corporate Policy. In the performance of the Services, Contractor shall comply with and observe all applicable laws, regulations and orders of any proper authority having jurisdiction over the Services together with all Corporate Policies of EFRI in effect from time to time. This Agreement shall be governed by and construed in accordance with the laws of the State of Colorado. Performance of Duties. Contractor shall perform his duties faithfully, efficiently and effectively and during the term of this Agreement shall devote such portion of his business time to the business affairs of EFRI and its affiliates as is reasonably necessary to accomplish the performance of the Services. The parties agree that Contractor’s engagement to provide Services is non-exclusive. Confidentiality. In consideration of the payments made under this Agreement, Contractor hereby acknowledges and agrees that, as a contractor providing Services during the term of this Agreement, Contractor’s relationship with EFRI is one of high trust and confidence and that Contractor has access to and will make use of a variety of proprietary information of EFRI and its affiliates, including information relating to EFRI’s and its affiliates’ business and affairs, including without limitation, its assets, profits, profit margins, revenues, costs of production, transportation costs, marketing and sales costs, budgets, business plans, regulatory compliance status, legal actions, software programs, manuals, guides, customer lists, client proposals, technical, geological and engineering data, maps, reports and analyses, process and mining technology, and other confidential documents and communications within or concerning EFRI and its affiliates and predecessors and previous owners and operators of EFRI’s assets which are not freely available to outsiders (herein collectively called “Proprietary Information”). Contractor covenants and agrees that (i) Contractor will not use for his own benefit or the benefit of any other party and will not disclose to any third party any Proprietary Information in Contractor’s possession or control without the express written consent of EFRI; and (ii) at the termination of this Agreement, Contractor will return all EFRI Proprietary Information then in Contractor’s possession or control, 2 including without limitation all files, data, computer software and programs, work in progress, customer lists, business plans, contracts, business proposals, cost and financial reports and analyses, and technical, geological and engineering reports and analyses, and further agrees to retain no duplicates or copies of any EFRI Proprietary Information without the express written consent of EFRI. The foregoing provisions, and all other provisions of this Agreement, are in addition to and do not alter or reduce any continuing provisions or obligations contained in or arising from the Employment Agreement made effective March 1, 2016 between Contractor, EFRI and Energy Fuels Inc. 9. Termination. EFRI may terminate this Agreement for “Cause” at any time after providing notice to Contractor. For purposes of this Agreement, “Cause” shall mean the following: (1) conviction of a crime involving a felony or, in the good faith judgment of EFRI, fraud, dishonesty, or moral turpitude; (2) deliberate and continual refusal to perform Services reasonably requested by EFRI; (3) fraud or embezzlement; (4) gross misconduct or gross negligence in connection with the business of EFRI; or (5) breach of any provision of this Agreement. Any determination of “cause” under this Agreement shall be made by EFRI after giving Contractor a reasonable opportunity to be heard. Termination for cause shall be effective upon the date of the notice by EFRI to Contractor of such termination. EFRI or Contractor may terminate this Agreement without Cause at any time after June 2, 2018 by providing no less than thirty (30) days written notice. In the event this Agreement is terminated without Cause, or expires by its terms, Contractor shall submit a final invoice for payment to EFRI. EFRI shall deliver a final payment to Contractor within ten (10) business days for any undisputed amounts. 10. Notices. Any notice required or permitted to be given hereunder shall be in writing and shall be sufficiently given if hand delivered or if mailed by prepaid registered mail addressed to the other party at the following addresses or to such other addresses as the parties may advise each other from time to time in writing. If to Contractor: If to EFRI: Daniel G. Zang 11896 W. Security Ave. Lakewood, CO 80401-4432 225 Union Blvd., Suite 600 Lakewood, Colorado 80228 USA Attention: David C. Frydenlund Any notice shall be deemed to have been received by the parties (a) if hand delivered and/or emailed on the date of delivery, or (b) if mailed on the fourth business day following the date of mailing, provided, that in the event of disruption of the postal system for any reason whatsoever, notice shall only be sufficiently delivered by hand. 11. Contractor understands that he has been selected by EFRI to Assignment; Binding Effect. provide the Services on the basis of his personal qualifications, experience and skills. Contractor agrees, therefore, that he cannot assign all or any portion of his performance under this Agreement without the 3 prior written consent of EFRI. Subject to the preceding two sentences, this Agreement shall be binding upon, inure to the benefit of, and be enforceable by the parties hereto and their respective heirs, legal representatives, successors, and assigns. 12. 13. 14. Arbitration. Any dispute arising in connection with this Agreement or Contractor’s provision of Services to EFRI shall be submitted to binding arbitration by an arbitrator with Judicial Arbiters Group (“JAG”) under the American Arbitration Association’s (“AAA”) rules for the resolution of disputes, in Denver, Colorado. Judgment upon any award rendered by arbitration may be entered in any court having jurisdiction thereof. The attorney’s fees and costs of the prevailing party in connection with the arbitration, as well as any costs of AAA, JAG, and the arbitrator shall be assessed against the losing party. Survival. The provisions set forth in Paragraphs 8 and 12 shall survive the termination of this Agreement. Entire Agreement. This Agreement (together with the Exhibits attached hereto) represents the entire understanding and agreement concerning the Services. Each of the parties shall from time to time and, at all times, do all further acts and execute and deliver all such further documents and assurances, as may be reasonably required, in order to fully perform and carry out the terms of this Agreement. This Agreement supersedes all prior understandings and agreements, whether written or oral, relating to the terms of this agreement, unless otherwise specified herein. IN WITNESS WHEREOF the parties hereto have executed this Agreement as of the 2nd day of March, 2018. ENERGY FUELS RESOURCES (USA) INC. DANIEL G. ZANG By: /s/ Mark S. Chalmers Name: Mark S. Chalmers Title: President & CEO By: /s/ Daniel G. Zang Daniel G. Zang Accounting Specialist 4 EXHIBIT “A” Scope of Services AS REQUESTED BY THE CHIEF FINANCIAL OFFICER Upon the reasonable request of EFRI’s Chief Financial Officer (the “Authorized EFRI Officer”), Contractor shall provide services to EFRI on a project-by-project basis in areas of financial statement preparation, cost accounting, internal controls, SOX compliance, budgeting, financial planning, financial analysis of projects, transitional matters and as otherwise may be required by EFRI and within Contractor’s areas of expertise. The Contractor shall spend time in the offices of EFRI as reasonably requested by the Authorized EFRI Officer or as may be required to complete any work or projects requested by the Authorized EFRI Officer. Contractor shall adhere to the following schedule unless requested otherwise by the Authorized EFRI Officer: • Contractor shall be available to perform services hereunder at the request of EFRI generally for a minimum of ten (10) working days per month consisting of 8 hours per day, on reasonable notice by the Company. Any additional hours or days shall be subject to Contractor’s availability and agreement. It is understood that Contractor reserves the right in any month to schedule ten (10) consecutive working days for activities not associated with this Agreement. • Contractor’s services hereunder shall be on an as-needed basis as requested by the Chief Financial Officer of EFRI, and EFRI shall be under no obligation to engage Contractor to provide any minimum amount of services or to pay any minimum amount of fees to Contractor hereunder. 5 EXHIBIT “B” Compensation for Services EFRI shall pay the following amounts to Contractor: • US$250.00 per hour of services performed hereunder at the request of EFRI. 6 ENERGY FUELS INC. – ENTITY ORGANIZATION CHART 2018 1 50% owned by EFR Colorado Plateau LLC 50% owned by Mesa Uranium 2 81% owned by Uranerz Energy Corporation 19% owned by United Nuclear, LLC 3 99% owned by EFR Recovery Corp., 1% owned by EFHC Energy Fuels Inc. (Ontario) 100% 100% 100% 100% Magnum Uranium Corp. (British Columbia) Titan Uranium Inc. (Canada) 100% Uranium Power Corp. (British Columbia) 3% 77% 20% Energy Fuels Holdings Corp. (Delaware) 100% Energy Fuels Exploration Inc. (Ontario) Strathmore Minerals Corp. (British Columbia) 100% 100% Wyoming Gold Mining Company (Wyoming) Strathmore Resources (US) Ltd. (Nevada) 100% Roca Honda Resources LLC (Delaware) Magnum Minerals USA Corp. (Nevada) Energy Fuels Wyoming Inc. (Nevada) EFR Arizona Strip LLC (Colorado) Energy Fuels Resources (USA) Inc. (Delaware) EFR Henry Mountains LLC (Colorado) Uranerz Energy Corp. (Nevada) Leoncito Plant LLC (Texas) Leoncito Project, LLC (Texas) EFR Alta Mesa LLC (Texas) EFR White Mesa LLC (Colorado) EFR Colorado Plateau LLC (Colorado) EFR Properties LLC (Colorado) EFR Recovery Corp. (Delaware) 100% 81% 100% 100% 100% 50% EFR White Canyon Corp. (Delaware) Wate Mining Company LLC (Arizona) Arkose Mining 2 Venture Leoncito Restoration LLC (Texas) Arizona Strip Partners LLC (Delaware) Colorado Plateau Partners LLC (Delaware) West Lisbon, LLC 1 (Delaware) 99% EFR Recovery 3 LLC (Delaware) Consent of Independent Registered Public Accounting Firm EX 23.1 The Board of Directors Energy Fuels Inc.: We consent to the incorporation by reference in the registration statements (Nos. 333-217098, 333-205182, and 333-194900) on Form S-8 and registration statement (No. 333-210782) on Form S-3 of Energy Fuels Inc. of our report dated March 9, 2018, with respect to the consolidated balance sheet of Energy Fuels Inc. as of December 31, 2017, and the related consolidated statements of operations and comprehensive loss, changes in equity, and cash flows for the year ended December 31, 2017, and the related notes (collectively, the consolidated financial statements), which report appears in the December 31, 2017 annual report on Form 10-K of Energy Fuels Inc. Denver, Colorado March 9, 2018 /s/ KPMG LLP CONSENT OF ROSCOE POSTLE ASSOCIATES INC. Exhibit 23.2 The undersigned hereby consents to: (i) (ii) (iii) the filing of the written disclosure regarding (a) the technical report entitled “Technical Report on the EZ1 and EZ2 Breccia Pipes, Arizona Strip District, U.S.A.” dated June 27, 2012; (b) the technical report entitled “Technical Report on the Henry Mountains Complex Uranium Property, Utah, U.S.A.” dated June 27, 2012; (c) the “Technical Report on the Roca Honda Project, McKinley County, State of New Mexico, U.S.A." dated October 27, 2016, and (d) the “Technical Report on the Canyon Mine, Coconino County, Arizona, USA” dated October 6, 2017 (collectively, the “Technical Disclosures”), contained in the Annual Report on Form 10-K for the period ended December 31, 2017 (the “10-K”) of Energy Fuels Inc. (the “Company”) being filed with the United States Securities and Exchange Commission; the incorporation by reference of such Technical Disclosures in the 10-K into the Company’s Form S-3 (File No. 333-210782), and any amendments thereto (the “S-3”); the incorporation by reference of such Technical Disclosures in the 10-K into the Company’s Form S-8 Registration Statements (File Nos. 333-217098, 333-205182 and 333-194900), and any amendments thereto (the “S-8s”); and (iv) the use of our name in the 10-K, the S-3, and the S-8s. ROSCOE POSTLE ASSOCIATES INC. /s/ Deborah A. McCombe Name: Deborah A. McCombe Title: President & CEO Date: March 9, 2018 RPA Inc. 55 University Ave. Suite 501 | Toronto, ON, Canada M5J 2H7 | T +1 (416) 947 0907 www.rpacan.com CONSENT OF WILLIAM E. ROSCOE Exhibit 23.3 The undersigned hereby consents to: (i) (ii) (iii) the filing of the written disclosure regarding the technical report entitled “Technical Report on the Henry Mountains Complex Uranium Property, Utah, U.S.A.” dated June 27, 2012 (the “Technical Disclosure”), contained in the Annual Report on Form 10-K for the period ended December 31, 2017 (the “10-K”) of Energy Fuels Inc. (the “Company”) being filed with the United States Securities and Exchange Commission; the incorporation by reference of such Technical Disclosure in the 10-K into the Company’s Form S-3 (File No. 333-210782), and any amendments thereto (the “S-3”); the incorporation by reference of such Technical Disclosure in the 10-K into the Company’s Form S-8 Registration Statements (File Nos. 333-217098, 333-205182 and 333-194900), and any amendments thereto (the “S-8s”); and (iv) the use of my name in the 10-K, the S-3, and the S-8s. /s/ William E. Roscoe William E. Roscoe, Ph.D. Date: March 9, 2018 RPA Inc. 55 University Ave. Suite 501 | Toronto, ON, Canada M5J 2H7 | T +1 (416) 947 0907 www.rpacan.com CONSENT OF DOUGLAS H. UNDERHILL Exhibit 23.4 The undersigned hereby consents to: (i) (ii) (iii) the filing of the written disclosure regarding the technical report entitled “Technical Report on the Henry Mountains Complex Uranium Property, Utah, U.S.A.” dated June 27, 2012 (the “Technical Disclosure”), contained in the Annual Report on Form 10-K for the period ended December 31, 2017 (the “10-K”) of Energy Fuels Inc. (the “Company”) being filed with the United States Securities and Exchange Commission; the incorporation by reference of such Technical Disclosure in the 10-K into the Company’s Form S-3 (File No. 333-210782), and any amendments thereto (the “S-3”); the incorporation by reference of such Technical Disclosure in the 10-K into the Company’s Form S-8 Registration Statements (File Nos. 333-217098, 333-205182 and 333-194900), and any amendments thereto (the “S-8s”); and (iv) the use of my name in the 10-K, the S-3, and the S-8s. /s/ Douglas H. Underhill Douglas H. Underhill, Ph.D., C.P.G Date: March 9, 2018 RPA Inc. 55 University Ave. Suite 501 | Toronto, ON, Canada M5J 2H7 | T +1 (416) 947 0907 www.rpacan.com CONSENT OF THOMAS C. POOL Exhibit 23.5 The undersigned hereby consents to: (i) (ii) (iii) the filing of the written disclosure (the “Technical Disclosure”) regarding the “Technical Report on the Henry Mountains Complex Uranium Property, Utah, U.S.A.” dated June 27, 2012, contained in the Annual Report on Form 10-K for the period ended December 31, 2017 (the “10-K”) of Energy Fuels Inc. (the “Company”) being filed with the United States Securities and Exchange Commission; the incorporation by reference of such Technical Disclosure in the 10-K into the Company’s Form S-3 (File No. 333-210782), and any amendments thereto (the “S-3”); the incorporation by reference of such Technical Disclosure in the 10-K into the Company’s Form S-8 Registration Statements (File Nos. 333-217098, 333-205182 and 333-194900), and any amendments thereto (the “S-8s”); and (iv) the use of my name in the 10-K, the S-3, and the S-8s. /s/ Thomas C. Pool Thomas C. Pool, P.E. Date: March 9, 2018 RPA Inc. 55 University Ave. Suite 501 | Toronto, ON, Canada M5J 2H7 | T +1 (416) 947 0907 www.rpacan.com CONSENT OF ROBERT MICHAUD Exhibit 23.6 The undersigned hereby consents to: (i) (ii) (iii) the filing of the written disclosure regarding the “Technical Report on the Roca Honda Project, McKinley County, State of New Mexico, U.S.A." dated October 27, 2016 (the “Technical Disclosure”), contained in the Annual Report on Form 10-K for the period ended December 31, 2017 (the “10-K”) of Energy Fuels Inc. (the “Company”) being filed with the United States Securities and Exchange Commission; the incorporation by reference of such Technical Disclosure in the 10-K into the Company’s Form S-3 (File No. 333-210782), and any amendments thereto (the “S-3”); the incorporation by reference of such Technical Disclosure in the 10-K into the Company’s Form S-8 Registration Statements (File Nos. 333-217098, 333-205182 and 333-194900), and any amendments thereto (the “S-8s”); and (iv) the use of my name in the 10-K, the S-3, and the S-8s. /s/ Robert Michaud Robert Michaud, Professional Engineer Date: March 9, 2018 RPA Inc. 55 University Ave. Suite 501 | Toronto, ON, Canada M5J 2H7 | T +1 (416) 947 0907 www.rpacan.com CONSENT OF STUART E. COLLINS Exhibit 23.7 The undersigned hereby consents to: (i) (ii) (iii) the filing of the written disclosure regarding the “Technical Report on the Roca Honda Project, McKinley County, State of New Mexico, U.S.A." dated October 27, 2016 (the “Technical Disclosure”), contained in the Annual Report on Form 10-K for the period ended December 31, 2017 (the “10-K”) of Energy Fuels Inc. (the “Company”) being filed with the United States Securities and Exchange Commission; the incorporation by reference of such Technical Disclosure in the 10-K into the Company’s Form S-3 (File No. 333-210782), and any amendments thereto (the “S-3”); the incorporation by reference of such Technical Disclosure in the 10-K into the Company’s Form S-8 Registration Statements (File Nos. 333-217098, 333-205182 and 333-194900), and any amendments thereto (the “S-8s”); and (iv) the use of my name in the 10-K, the S-3, and the S-8s. /s/ Stuart E. Collins Stuart E. Collins, Professional Engineer Date: March 9, 2018 RPA Inc. 55 University Ave. Suite 501 | Toronto, ON, Canada M5J 2H7 | T +1 (416) 947 0907 www.rpacan.com CONSENT OF MARK B. MATHISEN Exhibit 23.8 The undersigned hereby consents to: (i) (ii) (iii) the filing of the written disclosure regarding (a) the “Technical Report on the Roca Honda Project, McKinley County, State of New Mexico, U.S.A." dated October 27, 2016 (the “Technical Disclosure”), and (b) the “Technical Report on the Canyon Mine, Coconino County, Arizona, USA” dated October 6, 2017, contained in the Annual Report on Form 10-K for the period ended December 31, 2017 (the “10-K”) of Energy Fuels Inc. (the “Company”) being filed with the United States Securities and Exchange Commission; the incorporation by reference of such Technical Disclosure in the 10-K into the Company’s Form S-3 (File No. 333-210782), and any amendments thereto (the “S-3”); the incorporation by reference of such Technical Disclosure in the 10-K into the Company’s Form S-8 Registration Statements (File Nos. 333-217098, 333-205182 and 333-194900), and any amendments thereto (the “S-8s”); and (iv) the use of my name in the 10-K, the S-3, and the S-8s. /S/ Mark B. Mathisen Mark B. Mathisen C.P.G Date: March 9, 2018 RPA Inc. 55 University Ave. Suite 501 | Toronto, ON, Canada M5J 2H7 | T +1 (416) 947 0907 www.rpacan.com Exhibit 23.9 CONSENT OF HAROLD R. ROBERTS The undersigned hereby consents to: (i) (ii) (iii) (iv) the filing of the written disclosure regarding the “Technical Report on the Roca Honda Project, McKinley County, State of New Mexico, U.S.A." dated October 27, 2016 (the “Technical Disclosure”), contained in the Annual Report on Form 10-K for the period ended December 31, 2017 (the “10-K”) of Energy Fuels Inc. (the “Company”) being filed with the United States Securities and Exchange Commission; the incorporation by reference of such Technical Disclosure in the 10-K into the Company’s Form S-3 (File No. 333-210782), and any amendments thereto (the “S-3”); the incorporation by reference of such Technical Disclosure in the 10-K into the Company’s Form S-8 Registration Statements (File Nos. 333-217098, 333-205182 and 333-194900), and any amendments thereto (the “S-8s”); and the use of my name in the 10-K, the S-3, and the S-8s. /s/ Harold R. Roberts Harold R. Roberts, P.E., Executive Vice President and Chief Operating Officer of Energy Fuels Inc. Date: March 9, 2018 CONSENT OF DAVID A. ROSS Exhibit 23.10 The undersigned hereby consents to: (i) (ii) (iii) the filing of the written disclosure (the “Technical Disclosure”) regarding the “Technical Report on the EZ1 and EZ2 Breccia Pipes, Arizona Strip District, U.S.A.” dated June 27, 2012, contained in the Annual Report on Form 10-K for the period ended December 31, 2017 (the “10-K”) of Energy Fuels Inc. (the “Company”) being filed with the United States Securities and Exchange Commission; the incorporation by reference of such Technical Disclosure in the 10-K into the Company’s Form S-3 (File No. 333-210782), and any amendments thereto (the “S-3”); the incorporation by reference of such Technical Disclosure in the 10-K into the Company’s Form S-8 Registration Statements (File Nos. 333-217098, 333-205182 and 333-194900), and any amendments thereto (the “S-8s”); and (v) the use of my name in the 10-K, the S-3, and the S-8s. /s/ David A. Ross David A. Ross, P.Geo. Date: March 9, 2018 RPA Inc. 55 University Ave. Suite 501 | Toronto, ON, Canada M5J 2H7 | T +1 (416) 947 0907 www.rpacan.com CONSENT OF PETERS GEOSCIENCES Exhibit 23.11 The undersigned hereby consents to: (i) the filing of the written disclosure (the “Technical Disclosure”) regarding: (a) the technical report entitled “Updated Report on The Daneros Mine Project, San Juan County, Utah, U.S.A.” dated March 2, 2018; the technical report entitled “Updated Technical Report on Energy Fuels Resources Corporation’s Whirlwind Property (Including Whirlwind, Far West, and Crosswind Claim Groups and Utah State Metalliferous Minerals Lease ML-49312), Mesa County, Colorado and Grand County, Utah”, dated March 15, 2011; the technical report entitled “Updated Technical Report on Sage Plain Project (Including the Calliham Mine), San Juan County, Utah USA” dated March 18, 2015; and the technical report entitled “Technical Report on Energy Fuels Inc.’s La Sal District Project,” dated March 25, 2014, (b) (c) (d) contained in the Annual Report on Form 10-K for the period ended December 31, 2017 (the “10-K”) of Energy Fuels Inc. (the “Company”) being filed with the United States Securities and Exchange Commission; (ii) (iii) the incorporation by reference of such Technical Disclosure in the 10-K into the Company’s Form S-3 (File No. 333-210782), and any amendments thereto (the “S-3”); the incorporation by reference of such Technical Disclosure in the 10-K into the Company’s Form S-8 Registration Statements (File Nos. 333-217098, 333-205182 and 333-194900), and any amendments thereto (the “S-8s”); and (iv) the use of our name in the 10-K, the S-3, and the S-8s. PETERS GEOSCIENCES /s/ Douglas C. Peters Name: Douglas C. Peters Title: President Date: March 9, 2018 CONSENT OF DOUGLAS C. PETERS The undersigned hereby consents to: Exhibit 23.12 (i) the filing of the written disclosure (the “Technical Disclosure”) regarding: (a) the technical report entitled “Updated Report on The Daneros Mine Project, San Juan County, Utah, U.S.A.” dated March 2, 2018; the technical report entitled “Updated Technical Report on Energy Fuels Resources Corporation’s Whirlwind Property (Including Whirlwind, Far West, and Crosswind Claim Groups and Utah State Metalliferous Minerals Lease ML-49312), Mesa County, Colorado and Grand County, Utah”, dated March 15, 2011; the technical report entitled “Updated Technical Report on Sage Plain Project (Including the Calliham Mine), San Juan County, Utah USA” dated March 18, 2015; and the technical report entitled “Technical Report on Energy Fuels Inc.’s La Sal District Project,” dated March 25, 2014, (b) (c) (d) contained in the Annual Report on Form 10-K for the period ended December 31, 2017 (the “10-K”) of Energy Fuels Inc. (the “Company”) being filed with the United States Securities and Exchange Commission; (ii) (iii) the incorporation by reference of such Technical Disclosure in the 10-K into the Company’s Form S-3 (File No. 333-210782), and any amendments thereto (the “S-3”); the incorporation by reference of such Technical Disclosure in the 10-K into the Company’s Form S-8 Registration Statements (File Nos. 333-217098, 333-205182 and 333-194900), and any amendments thereto (the “S-8s”); and (iv) the use of my name in the 10-K, the S-3, and the S-8s. /s/ Douglas C. Peters Douglas C. Peters, Certified Professional Geologist Date: March 9, 2018 CONSENT OF BRS INC. Exhibit 23.13 The undersigned hereby consents to: (i) (ii) (iii) the filing of the written disclosure (the “Technical Disclosure”) regarding (a) the technical report entitled “Sheep Mountain Uranium Project, Fremont County, Wyoming, USA, Updated Preliminary Feasibility Study, National Instrument 43-101 Technical Report” dated April 13, 2012, (b) the technical report entitled “Nichols Ranch Uranium Project, 43-101 Technical Report, Preliminary Economic Assessment” dated February 28, 2015, (c) the “Arkose Uranium Project, Mineral Resource and Exploration Target, 43-101 Technical Report” dated February 28, 2015, and (d) the “Alta Mesa Uranium Project, Alta Mesa and Mesteña Grande Mineral Resources and Exploration Target, Technical Report National Instrument 43-101”, dated July 19, 2016, contained in the Annual Report on Form 10-K for the period ended December 31, 2017 (the “10-K”) of Energy Fuels Inc. (the “Company”) being filed with the United States Securities and Exchange Commission; the incorporation by reference of such Technical Disclosure in the 10-K into the Company’s Form S-3 (File No. 333-210782), and any amendments thereto (the “S-3”); the incorporation by reference of such Technical Disclosure in the 10-K into the Company’s Form S-8 Registration Statements (File Nos. 333-217098, 333-205182 and 333-194900), and any amendments thereto (the “S-8s”); and (iv) the use of our name in the 10-K, the S-3, and the S-8s. BRS INC. /s/ Douglas L. Beahm Name: Douglas L. Beahm Title: President Date: March 9, 2018 CONSENT OF DOUGLAS L. BEAHM Exhibit 23.14 The undersigned hereby consents to: (i) (ii) (iii) the filing of the written disclosure (the “Technical Disclosure”) regarding (a) the technical report entitled “Sheep Mountain Uranium Project, Fremont County, Wyoming, USA, Updated Preliminary Feasibility Study, National Instrument 43-101 Technical Report” dated April 13, 2012, (b) the technical report entitled “Nichols Ranch Uranium Project, 43-101 Technical Report, Preliminary Economic Assessment” dated February 28, 2015, (c) the “Arkose Uranium Project, Mineral Resource and Exploration Target, 43-101 Technical Report” dated February 28, 2015, and (d) the “Alta Mesa Uranium Project, Alta Mesa and Mesteña Grande Mineral Resources and Exploration Target, Technical Report National Instrument 43-101”, dated July 19, 2016, contained in the Annual Report on Form 10-K for the period ended December 31, 2017 (the “10-K”) of Energy Fuels Inc. (the “Company”) being filed with the United States Securities and Exchange Commission; the incorporation by reference of such Technical Disclosure in the 10-K into the Company’s Form S-3 (File No. 333-210782), and any amendments thereto (the “S-3”); the incorporation by reference of such Technical Disclosure in the 10-K into the Company’s Form S-8 Registration Statements (File Nos. 333-217098, 333-205182 and 333-194900), and any amendments thereto (the “S-8s”); and (iv) the use of my name in the 10-K, the S-3, and the S-8s. /s/ Douglas L. Beahm Douglas L. Beahm, P.E., P.G. Date: March 9, 2018 CONSENT OF WILLIAM PAUL GORANSON Exhibit 23.15 The undersigned hereby consents to: (i) (ii) (iii) the filing of the written disclosure (the “Technical Disclosure”) regarding the “Nichols Ranch Uranium Project, 43-101 Technical Report, Preliminary Economic Assessment” dated February 28, 2015, contained in the Annual Report on Form 10-K for the period ended December 31, 2017 (the “10-K”) of Energy Fuels Inc. (the “Company”) being filed with the United States Securities and Exchange Commission; the incorporation by reference of such Technical Disclosure in the 10-K into the Company’s Form S-3 (File No. 333-210782), and any amendments thereto (the “S-3”); the incorporation by reference of such Technical Disclosure in the 10-K into the Company’s Form S-8 Registration Statements (File Nos. 333-217098, 333-205182 and 333-194900), and any amendments thereto (the “S-8s”); and (iv) the use of my name in the 10-K, the S-3, and the S-8s. /s/ William Paul Goranson William Paul Goranson, P.E Date: March 9, 2018 CONSENT OF DOUGLASS H. GRAVES Exhibit 23.16 The undersigned hereby consents to: (i) (ii) (iii) the filing of the written disclosure (the “Technical Disclosure”) regarding (a) the technical report entitled “Technical Report, North Rolling Pin Property, Campbell County, Wyoming, U.S.A.” dated June 4, 2010, (b) the technical report entitled “Technical Report, West North Butte Satellite Properties, Campbell County, Wyoming, U.S.A.” dated December 9, 2008, and (c) the technical report entitled “Technical Report, Reno Creek Property, Campbell County, Wyoming, U.S.A.” dated October 13, 2010, contained in the Annual Report on Form 10-K for the period ended December 31, 2017 (the “10-K”) of Energy Fuels Inc. (the “Company”) being filed with the United States Securities and Exchange Commission; the incorporation by reference of such Technical Disclosure in the 10-K into the Company’s Form S-3 (File No. 333-210782), and any amendments thereto (the “S-3”); the incorporation by reference of such Technical Disclosure in the 10-K into the Company’s Form S-8 Registration Statements (File Nos. 333-217098, 333-205182 and 333-194900), and any amendments thereto (the “S-8s”); and (iv) the use of my name in the 10-K, the S-3, and the S-8s. /s/ Douglas H. Graves Douglass H. Graves, P.E. Date: March 9, 2018 CONSENT OF JOHN H. WHITE Exhibit 23.17 The undersigned hereby consents to: (i) (ii) (iii) (iv) the filing of the written disclosure regarding certain scientific or technical information concerning mineral projects (the “Technical Disclosure”) contained in the Annual Report on Form 10-K for the period ended December 31, 2017 (the “10-K”) of Energy Fuels Inc. (the “Company”) being filed with the United States Securities and Exchange Commission; the incorporation by reference of such Technical Disclosure in the 10-K into the Company’s Form S-3 (File No. 333-210782), and any amendments thereto (the “S-3”); the incorporation by reference of such Technical Disclosure in the 10-K into the Company’s Form S-8 Registration Statements (File Nos. 333-217098, 333-205182 and 333-194900), and any amendments thereto (the “S-8s”); and the use of my name in the 10-K, the S-3, and the S-8s. /s/ John H. White John H. White, P.E., Vice President, Technical Services of Energy Fuels Inc. Date: March 8, 2018 CONSENT OF DON R. WOODY Exhibit 23.18 The undersigned hereby consents to: (i) (ii) (iii) the filing of the written disclosure (the “Technical Disclosure”) regarding the “Technical Report, West North Butte Satellite Properties, Campbell County, Wyoming, U.S.A.” dated December 9, 2008, contained in the Annual Report on Form 10-K for the period ended December 31, 2017 (the “10-K”) of Energy Fuels Inc. (the “Company”) being filed with the United States Securities and Exchange Commission; the incorporation by reference of such Technical Disclosure in the 10-K into the Company’s Form S-3 (File No. 333-210782), and any amendments thereto (the “S-3”); the incorporation by reference of such Technical Disclosure in the 10-K into the Company’s Form S-8 Registration Statements (File Nos. 333-217098, 333-205182 and 333-194900), and any amendments thereto (the “S-8s”); and (iv) the use of my name in the 10-K, the S-3, and the S-8s. /s/ Don R. Woody Don R. Woody Date: March 9, 2018 CONSENT OF TREC, INC. Exhibit 23.19 The undersigned hereby consents to: (i) (ii) (iii) the filing of the written disclosure (the “Technical Disclosure”) regarding (a) the technical report entitled “Technical Report, North Rolling Pin Property, Campbell County, Wyoming, U.S.A.” dated June 4, 2010, (b) the technical report entitled “Technical Report, West North Butte Satellite Properties, Campbell County, Wyoming, U.S.A.” dated December 9, 2008, and (c) the technical report entitled “Technical Report, Reno Creek Property, Campbell County, Wyoming, U.S.A.” dated October 13, 2010, contained in the Annual Report on Form 10-K for the period ended December 31, 2017 (the “10-K”) of Energy Fuels Inc. (the “Company”) being filed with the United States Securities and Exchange Commission; the incorporation by reference of such Technical Disclosure in the 10-K into the Company’s Form S-3 (File No. 333-210782), and any amendments thereto (the “S-3”); the incorporation by reference of such Technical Disclosure in the 10-K into the Company’s Form S-8 Registration Statements (File Nos. 333-217098, 333-205182 and 333-194900), and any amendments thereto (the “S-8s”); and (iv) the use of our name in the 10-K, the S-3, and the S-8s. TREC, INC. /s/ Douglass H. Graves Name: Douglass H. Graves Title: President Date: March 9, 2018 CONSENT OF WOODY ENTERPRISES Exhibit 23.20 The undersigned hereby consents to: (i) (ii) (iii) the filing of the written disclosure (the “Technical Disclosure”) regarding the “Technical Report, West North Butte Satellite Properties, Campbell County, Wyoming, U.S.A.” dated December 9, 2008, contained in the Annual Report on Form 10-K for the period ended December 31, 2017 (the “10-K”) of Energy Fuels Inc. (the “Company”) being filed with the United States Securities and Exchange Commission; the incorporation by reference of such Technical Disclosure in the 10-K into the Company’s Form S-3 (File No. 333-210782), and any amendments thereto (the “S-3”); the incorporation by reference of such Technical Disclosure in the 10-K into the Company’s Form S-8 Registration Statements (File Nos. 333-217098, 333-205182 and 333-194900), and any amendments thereto (the “S-8s”); and (iv) the use of our name in the 10-K, the S-3, and the S-8s. WOODY ENTERPRISES /s/ Don R. Woody Name: Don R. Woody Date: March 9, 2018 CONSENT OF ALLAN MORAN Exhibit 23.21 The undersigned hereby consents to: (i) (ii) (iii) the filing of the written disclosure regarding the technical report entitled “NI 43-101 Technical Report on Resources Wate Uranium Breccia Pipe - Northern Arizona, USA” dated March 10, 2015 (the “Technical Disclosure”), contained in the Annual Report on Form 10-K for the period ended December 31, 2017 (the “10-K”) of Energy Fuels Inc. (the “Company”) being filed with the United States Securities and Exchange Commission; the incorporation by reference of such Technical Disclosure in the 10-K into the Company’s Form S-3 (File No. 333-210782), and any amendments thereto (the “S-3”); the incorporation by reference of such Technical Disclosure in the 10-K into the Company’s Form S-8 Registration Statements (File Nos. 333-217098, 333-205182 and 333-194900), and any amendments thereto (the “S-8s”); and (iv) the use of my name in the 10-K, the S-3, and the S-8s. /s/ Allan Moran Allan Moran Date: March 9, 2018 Exhibit 23.22 CONSENT OF FRANK A. DAVIESS The undersigned hereby consents to: (i) (ii) (iii) the filing of the written disclosure regarding the technical report entitled “NI 43-101 Technical Report on Resources Wate Uranium Breccia Pipe - Northern Arizona, USA” dated March 10, 2015 (the “Technical Disclosure”), contained in the Annual Report on Form 10-K for the period ended December 31, 2017 (the “10-K”) of Energy Fuels Inc. (the “Company”) being filed with the United States Securities and Exchange Commission; the incorporation by reference of such Technical Disclosure in the 10-K into the Company’s Form S-3 (File No. 333-210782), and any amendments thereto (the “S-3”); the incorporation by reference of such Technical Disclosure in the 10-K into the Company’s Form S-8 Registration Statements (File Nos. 333-217098, 333-205182 and 333-194900), and any amendments thereto (the “S-8s”); and (iv) the use of my name in the 10-K, the S-3, and the S-8s. /s/ Frank A. Daviess Frank A. Daviess Date: March 9, 2018 Exhibit 23.23 CONSENT OF SRK CONSULTING (U.S.) INC. The undersigned hereby consents to: (i) (ii) (iii) the filing of the written disclosure regarding the technical report entitled “NI 43-101 Technical Report on Resources Wate Uranium Breccia Pipe - Northern Arizona, USA” dated March 10, 2015 (the “Technical Disclosure”), contained in the Annual Report on Form 10-K for the period ended December 31, 2017 (the “10-K”) of Energy Fuels Inc. (the “Company”) being filed with the United States Securities and Exchange Commission; the incorporation by reference of such Technical Disclosure in the 10-K into the Company’s Form S-3 (File No. 333-210782), and any amendments thereto (the “S-3”); the incorporation by reference of such Technical Disclosure in the 10-K into the Company’s Form S-8 Registration Statements (File Nos. 333-217098, 333-205182 and 333-194900), and any amendments thereto (the “S-8s”); and (iv) the use of our name in the 10-K, the S-3, and the S-8s. SRK CONSULTING (U.S.) INC. /s/ Corolla Hoag Name: Corolla Hoag Title: Practice Leader Date: March 9, 2018 Exhibit 23.24 CONSENT OF CHRISTOPHER MORETON The undersigned hereby consents to: (i) (ii) (iii) the filing of the written disclosure (the “Technical Disclosure”) regarding the “Technical Report on the EZ1 and EZ2 Breccia Pipes, Arizona Strip District, U.S.A.” dated June 27, 2012, contained in the Annual Report on Form 10-K for the period ended December 31, 2017 (the “10-K”) of Energy Fuels Inc. (the “Company”) being filed with the United States Securities and Exchange Commission; the incorporation by reference of such Technical Disclosure in the 10-K into the Company’s Form S-3 (File No. 333-210782), and any amendments thereto (the “S-3”); the incorporation by reference of such Technical Disclosure in the 10-K into the Company’s Form S-8 Registration Statements (File Nos. 333-217098, 333-205182 and 333-194900), and any amendments thereto (the “S-8s”); and (v) the use of my name in the 10-K, the S-3, and the S-8s. /s/ Christopher Moreton Christopher Moreton, P.E. Date: March 8, 2018 RPA Inc. 55 University Ave. Suite 501 | Toronto, ON, Canada M5J 2H7 | T +1 (416) 947 0907 www.rpacan.com CONSENT OF VALERIE WILSON The undersigned hereby consents to: (i) the filing of the written disclosure regarding the “Technical Report on the Canyon Mine, Coconino County, Arizona, USA” dated October 6, 2017 (the “Technical Disclosure”), contained in the Annual Report on Form 10-K for the period ended December 31, 2017 (the “10-K”) of Energy Fuels Inc. (the “Company”) being filed with the United States Securities and Exchange Commission; (ii) the incorporation by reference of such Technical Disclosure in the 10-K into the Company’s Form S-3 (File No. 333-210782), and any amendments thereto (the “S-3”); (iii) the incorporation by reference of such Technical Disclosure in the 10-K into the Company’s Form S-8 Registration Statements (File Nos. 333-217098, 333-205182 and 333-194900), and any amendments thereto (the “S-8s”); and (iv) the use of my name in the 10-K, the S-3, and the S-8s. /s/ Valerie Wilson Valerie Wilson, M.Sc., P.Geo. Date: March 9, 2018 RPA Inc. 55 University Ave. Suite 501 | Toronto, ON, Canada M5J 2H7 | T +1 (416) 947 0907 www.rpacan.com CONSENT OF JEFFREY L. WOODS The undersigned hereby consents to: (i) the filing of the written disclosure regarding the “Technical Report on the Canyon Mine, Coconino County, Arizona, USA” dated October 6, 2017 (the “Technical Disclosure”), contained in the Annual Report on Form 10-K for the period ended December 31, 2017 (the “10-K”) of Energy Fuels Inc. (the “Company”) being filed with the United States Securities and Exchange Commission; (ii) the incorporation by reference of such Technical Disclosure in the 10-K into the Company’s Form S-3 (File No. 333-210782), and any amendments thereto (the “S-3”); (iii) the incorporation by reference of such Technical Disclosure in the 10-K into the Company’s Form S-8 Registration Statements (File Nos. 333-217098, 333-205182 and 333-194900), and any amendments thereto (the “S-8s”); and (iv) the use of my name in the 10-K, the S-3, and the S-8s. Jeffrey L. Woods Jeffrey L. Woods, SME, QP MMSA Date: March 9, 2018 RPA Inc. 55 University Ave. Suite 501 | Toronto, ON, Canada M5J 2H7 | T +1 (416) 947 0907 www.rpacan.com KPMG LLP Chartered Accountants Bay Adelaide Centre Suite 4600 333 Bay Street Toronto ON M5H 2S5 Telephone (416) 777-8500 Fax (416) 777-8818 www.kpmg.ca CONSENT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM The Board of Directors Energy Fuels Inc. We consent to the incorporation by reference in the Registration Statement (No. 333-210782) on Form S-3 and Registration Statements (No. 333-217098, 333-205182, 333-194900) on Form S-8 of Energy Fuels Inc. of our report dated March 8, 2017, with respect to the consolidated balance sheet of Energy Fuels Inc. as of December 31, 2016, and the related consolidated statements of operations and comprehensive loss, changes in equity and cash flows for each of the years in the two-year period ended December 31, 2016, which report appears in the December 31, 2017 Annual Report on Form 10-K of Energy Fuels Inc. /s/ KPMG LLP Chartered Professional Accountants, Licensed Public Accountants March 9, 2018 Toronto, Canada KPMG LLP is a Canadian limited liability partnership and a member firm of the KPMG network of independent member firms affiliated with KPMG International Cooperative (“KPMG International”), a Swiss entity. KPMG Canada provides services to KPMG LLP. CERTIFICATION OF CHIEF EXECUTIVE OFFICER PURSUANT TO RULE 13a-14(a) OF THE SECURITIES EXCHANGE ACT OF 1934 I, Mark S. Chalmers, certify that: EXHIBIT 31.1 1. 2. 3. 4. I have reviewed this annual report on Form 10-K of Energy Fuels Inc.; Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report; Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report; The registrant's other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have: (a) (b) (c) (d) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared; Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles; Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and 5. The registrant's other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions): (a) (b) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting. Date: March 9, 2018 /s/ Mark S. Chalmers Mark S. Chalmers Chief Executive Officer (Principal Executive Officer) CERTIFICATION OF CHIEF FINANCIAL OFFICER PURSUANT TO RULE 13a-14(a) OF THE SECURITIES EXCHANGE ACT OF 1934 I, David C. Frydenlund, certify that: EXHIBIT 31.2 1. 2. 3. 4. I have reviewed this annual report on Form 10-K of Energy Fuels Inc.; Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report; Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report; The registrant's other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have: (a) (b) (c) (d) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared; Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles; Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and 5. The registrant's other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions): (a) (b) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting. Date: March 9, 2018 /s/ David C. Frydenlund David C. Frydenlund Chief Financial Officer (Principal Financial Officer) CERTIFICATION PURSUANT TO 18 U.S.C. §1350 AS ADOPTED PURSUANT TO SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002 EXHIBIT 32.1 In connection with the Annual Report of Energy Fuels Inc. (the "Company") on Form 10-K for the period ended December 31, 2017 as filed with the Securities and Exchange Commission on the date hereof (the "Report"), I, Mark S. Chalmers, Chief Executive Officer, certify, pursuant to 18 U.S.C. §1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that: (1) The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934, as amended; and (2) The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company. /s/ Mark S. Chalmers Mark S. Chalmers Chief Executive Officer (Principal Executive Officer) Date: March 9, 2018 A signed original of this written statement required by Section 906, or other document authenticating, acknowledging, or otherwise adopting the signature that appears in typed form within the electronic version of this written statement required by Section 906, has been provided to the Company and will be retained by the Company and furnished to the Securities and Exchange Commission or its staff upon request. CERTIFICATION PURSUANT TO 18 U.S.C. §1350 AS ADOPTED PURSUANT TO SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002 EXHIBIT 32.2 In connection with the Annual Report of Energy Fuels Inc. (the "Company") on Form 10-K for the period ended December 31, 2017 as filed with the Securities and Exchange Commission on the date hereof (the "Report"), I, David C. Frydenlund, Chief Financial Officer, certify, pursuant to 18 U.S.C. §1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that: (1) The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934, as amended; and (2) The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company. /s/ David C. Frydenlund David C. Frydenlund Chief Financial Officer (Principal Financial Officer) Date: March 9, 2018 A signed original of this written statement required by Section 906, or other document authenticating, acknowledging, or otherwise adopting the signature that appears in typed form within the electronic version of this written statement required by Section 906, has been provided to the Company and will be retained by the Company and furnished to the Securities and Exchange Commission or its staff upon request. Mine Safety Disclosure Exhibit 95.1 Pursuant to Section 1503(a) of the Dodd-Frank Wall Street Reform and Consumer Protection Act of 2010 (the “Dodd-Frank Act”), issuers that are operators, or that have a subsidiary that is an operator, of a coal or other mine in the United States, and that is subject to regulation by the Federal Mine Safety and Health Administration under the Mine Safety and Health Act of 1977 (“Mine Safety Act”), are required to disclose in their periodic reports filed with the SEC information regarding specified health and safety violations, orders and citations, related assessments and legal actions, and mining-related fatalities. The following table sets out the information concerning mine safety violations or other regulatory matters required by Section 1503(a) of the Dodd Frank Wall Street Reform and Consumer Protection Act for the period January 1, 2017 through December 31, 2017 covered by this report: Section 104 (a) S&S Citations2 (#) Section 104(b) Orders3 Section 110 (b)(2) Violations5 (#) Section 107(a) Orders6 Section 104(d) Citations and Orders4 (#) Nil Nil Nil Nil Nil Nil Nil Nil Nil Nil (#) Nil Nil Nil Nil Nil Nil Nil Nil Nil Nil Nil Nil Nil Nil Nil Nil Nil Nil Nil Nil Property Arizona 1 Beaver/ La Sal1 Canyon Daneros1 Energy Queen1 Pandora1 Pinenut1 Rim1 Tony M1 Whirlwind1 Nil Nil 4 Nil Nil Nil Nil Nil Nil Nil Total Dollar Value of MSHA Assess- ments Proposed7 ($) $0.00 $0.00 $5,124.00 $0.00 $0.00 $0.00 $0.00 $0.00 $0.00 $0.00 Total Number of Mining Related Fatalities (#) Nil Nil Nil Nil Nil Nil Nil Nil Nil Nil Received Notice of Pattern of Violations Legal or Potential Actions Thereof Under Section 104 (e)8 (yes/no) Legal Pending Actions as of Last Day of Period9 (#) Legal Actions Initiated Resolved During During Period Period (#) (#) No No No No No No No No No No Nil Nil Nil Nil Nil Nil Nil Nil Nil Nil Nil Nil Nil Nil Nil Nil Nil Nil Nil Nil Nil Nil Nil Nil Nil Nil Nil Nil Nil Nil (#) Nil Nil Nil Nil Nil Nil Nil Nil Nil Nil 1. The Company’s Arizona 1, Beaver/La Sal Property, Daneros Project, Energy Queen Property, Pandora Property, Pinenut, Rim Project, Tony M Property and Whirlwind Project were each on standby and were not mined during the period. 2. Citations and Orders are issued under Section 104 of the Federal Mine Safety and Health Act of 1977 (30 U.S.C. 814) (the “Act”) for violations of the Act or any mandatory health or safety standard, rule, order or regulation promulgated under the Act. A Section 104(a) “Significant and Substantial” or “S&S” citation is considered more severe than a non-S&S citation and generally is issued in a situation where the conditions created by the violation do not cause imminent danger, but the violation is of such a nature as could significantly and substantially contribute to the cause and effect of a mine safety or health hazard. It should be noted that, for purposes of this table, S&S citations that are included in another column, such as Section 104(d) citations, are not also included as Section 104(a) S&S citations in this column. 3. A Section 104(b) withdrawal order is issued if, upon a follow up inspection, an MSHA inspector finds that a violation has not been abated within the period of time as originally fixed in the violation and determines that the period of time for the abatement should not be extended. Under a withdrawal order, all persons, other than those required to abate the violation and certain others, are required to be withdrawn from and prohibited from entering the affected area of the mine until the inspector determines that the violation has been abated. 4. A citation is issued under Section 104(d) where there is an S&S violation and the inspector finds the violation to be caused by an unwarrantable failure of the operator to comply with a mandatory health or safety standard. Unwarrantable failure is a special negligence finding that is made by an MSHA inspector and that focuses on the operator’s conduct. If during the same inspection or any subsequent inspection of the mine within 90 days after issuance of the citation, the MSHA inspector finds another violation caused by an unwarrantable failure of the operator to comply, a withdrawal order is issued, under which all persons, other than those required to abate the violation and certain others, are required to be withdrawn from and prohibited from entering the affected area until the inspector determines that the violation has been abated. 5. A flagrant violation under Section 110(b)(2) is a violation that results from a reckless or repeated failure to make reasonable efforts to eliminate a known violation of a mandatory health or safety standard that substantially and proximately caused, or reasonable could have been expected to cause, death or serious bodily injury. 6. An imminent danger order under Section 107(a) is issued when an MSHA inspector finds that an imminent danger exists in a mine. An imminent danger is the existence of any condition or practice which could reasonably be expected to cause death or serious physical harm before such condition or practice can be abated. Under an imminent danger order, all persons, other than those required to abate the condition or practice and certain others, are required to be withdrawn from and are prohibited from entering the affected area until the inspector determines that such imminent danger and the conditions or practices which caused the imminent danger no longer exist. 7. These dollar amounts include the total amount of all proposed assessments from MSHA under the Act relating to any type of violation during the period, including proposed assessments for non-S&S citations that are not specifically identified in this exhibit, regardless of whether the Company has challenged or appealed the assessment. 8. A Notice is given under Section 104(e) if an operator has a pattern of S&S violations. If upon any inspection of the mine within 90 days after issuance of the notice, or at any time after a withdrawal notice has been given under Section 104(e), an MSHA inspector finds another S&S violation, an order is issued, under which all persons, other than those required to abate the violation and certain others, are required to be withdrawn from and prohibited from entering the affected area until the inspector determines that the violation has been abated. 9. There were no legal actions pending before the Federal Mine Safety and Health Review Commission as of the last day of the period covered by this report. In addition, there were no pending actions that are (a) contests of citations and orders referenced in Subpart B of 29 CFR Part 2700; (b) complaints for compensation referenced in subpart D of 29 CFR Part 2700; (c) complaints of discharge, discrimination or interference referenced in Subpart E of 29 CFR Part 2700; (d) applications for temporary relief referenced in Subpart F of 29 CFR Part 2700; or (e) appeals of judges’ decisions or orders to the Federal Mine Safety and Health Review Commission referenced in Subpart H of 29 CFR Part 2700. 

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