UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D.C. 20549

FORM 10-K

(Mark One)
[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 001-33404

WESTWATER RESOURCES, INC.

(Exact name of Registrant as specified in its charter)

DELAWARE	75-2212772
(State of Incorporation)	(I.R.S. Employer Identification No.)

6950 S. Potomac Street, Suite 300 Centennial, Colorado	80112
(Address of principal executive offices)	(Zip code)

(303) 531-0516

(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 Stock, $0.001 par value per share	NASDAQ Capital Market
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 check mark whether the Registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the Registrant was required to file such reports) and (2) has been subject to such filing requirements for the past 90 days. Yes [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 (§ 232.405 of this chapter) during the preceding 12 months (or for such shorter period that the Registrant was required to submit and post such files). Yes [X] No [  ]

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

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

Large accelerated filer [  ]	Accelerated filer [  ]	Non-accelerated filer [  ]	Smaller reporting company [X]
		(Do not check if a smaller reporting company)	Emerging growth company [  ]

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

Indicate by check mark whether the Registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). Yes [  ] No [X]

The aggregate market value of the Common Stock held by non-affiliates of the Registrant at June 30, 2017, was approximately $36,767,717. Number of shares of Common Stock, $0.001 par value, outstanding as of March 1, 2018 was 27,929,194 shares.

DOCUMENTS INCORPORATED BY REFERENCE

Portions of the definitive proxy statement relating to Registrant’s 2018 Annual Meeting of Stockholders are incorporated by reference into Part III of this Form 10-K.

WESTWATER RESOURCES, INC.

ANNUAL REPORT ON FORM 10-K

FOR THE FISCAL YEAR ENDED DECEMBER 31, 2017

TABLE OF CONTENTS

GLOSSARY OF CERTAIN ENERGY MINERALS INDUSTRY TERMS		4
PART I		8
ITEM 1. DESCRIPTION OF BUSINESS.		8
	THE COMPANY	8
	OUR STRATEGY	8
	RECENT CORPORATE DEVELOPMENTS	8
	OVERVIEW OF THE URANIUM INDUSTRY	11
	COMPETITION	12
	OVERVIEW OF WWR PROJECTS	12
	THE ISR PROCESS	14
	ENVIRONMENTAL CONSIDERATIONS AND PERMITTING	14
	AVAILABLE INFORMATION	19
ITEM 1A. RISK FACTORS		19
ITEM 1B. UNRESOLVED STAFF COMMENTS		27
ITEM 2. PROPERTIES		28
	URANIUM PROCESSING FACILITIES	28
	LITHIUM PROPERTIES	29
	URANIUM PROPERTIES	36
	SOUTH TEXAS PROPERTIES AND EXPLORATION PROJECTS	41
	NEW MEXICO PROJECTS	50
	OTHER	55
	WORK COMPLETED ON PROPERTIES IN 2016	56
	INFRASTRUCTURE	56
	INSURANCE	56
ITEM 3. LEGAL PROCEEDINGS		57
	DISPUTE OVER KLEBERG SETTLEMENT AGREEMENT	57
	OTHER	57
ITEM 4. MINE SAFETY DISCLOSURES		57
PART II		58
ITEM 5.MARKET FOR REGISTRANT’S COMMON EQUITY, RELATED STOCKHOLDER MATTERS AND ISSUER PURCHASES OF EQUITY SECURITIES		58
	STOCK PRICE INFORMATION	58
	DIVIDENDS	58

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ITEM 6. SELECTED FINANCIAL DATA		58
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS		58
	INTRODUCTION	58
	RECENT DEVELOPMENTS	59
	FINANCIAL POSITION	65
ITEM 7A.QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK		66
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA		67
	REPORTS OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRMS	67
	NOTES TO CONSOLIDATED FINANCIAL STATEMENTS	73
ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND FINANCIAL DISCLOSURE.		95
ITEM 9A.CONTROLS AND PROCEDURES		95
	EVALUATION OF DISCLOSURE CONTROLS AND PROCEDURES	95
	MANAGEMENT’S REPORT ON INTERNAL CONTROL OVER FINANCIAL REPORTING	95
ITEM 9B.OTHER INFORMATION		96
PART III		96
ITEM 10. DIRECTORS, EXECUTIVE OFFICERS AND CORPORATE GOVERNANCE		96
ITEM 11. EXECUTIVE COMPENSATION		96
ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT AND RELATED STOCKHOLDER MATTERS		96
ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS AND DIRECTOR INDEPENDENCE		96
ITEM 14. PRINCIPAL ACCOUNTANT FEES AND SERVICES		96
PART IV		97
ITEM 15. EXHIBITS AND FINANCIAL STATEMENT SCHEDULES		97
ITEM 16. FORM 10-K SUMMARY		98
SIGNATURES		99

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GLOSSARY OF CERTAIN ENERGY MINERALS INDUSTRY TERMS

Brine	A naturally occurring fluid generally hosted in sedimentary rocks. Its chemical make-up is generally saline and may contain appreciable levels of potash (potassium chloride), magnesium and/or lithium.
Claim	A claim is a tract of land up to 20 acres in size, of which the right to mine is held under the federal General Mining Law of 1872 and applicable local laws.
Concentrates	A product from a mineral processing facility (including uranium). Uranium concentrates are commonly referred to as U3O8.
Gross acres	Total acreage of land under which we have mineral rights. May include unleased fractional ownership.
Indian Country	A term derived from jurisdictional determinations in criminal law enforcement proceedings under 18 U.S.C. § 1151 and understood to encompass territory situated within Indian reservations, land owned by Indian Allottees and land within a dependent Indian community.
In-situ recovery (“ISR”)	Groundwater fortified with oxygen and other solubilizing agents is pumped into a permeable ore body causing the uranium contained in the ore to dissolve. The resulting solution is pumped to the surface. The fluid-bearing uranium is then circulated to an ion exchange column on the surface where uranium is extracted from the fluid onto resin beads. The fluid is then reinjected into the ore body. When the ion exchange column’s resin beads are loaded with uranium, they are removed and flushed with a salt-water solution, which strips the uranium from the beads. This leaves the uranium in slurry, which is then dried and packaged for shipment as uranium powder, or yellowcake.
Mineral Resource	A mineralized body which has been delineated by appropriately spaced drilling and/or underground sampling to support a sufficient tonnage and average grade. Such a deposit does not qualify as a reserve, until a comprehensive evaluation based upon unit cost, grade, recoveries, and other material factors conclude legal and economic feasibility.
Net acres	Actual acres under lease which may differ from gross acres when fractional mineral interests are not leased.
Ore	Naturally occurring material from which a mineral or minerals of economic value can be extracted at a reasonable profit.
Probable 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 (measured) reserves, is high enough to assume continuity between points of observation.
Proven reserves	Reserves for which (a) quantity is computed from dimensions revealed in outcrops, trenches, workings 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 geologic character is so well defined that size, shape, depth and mineral content of reserves are well-established.
Reclamation	Reclamation involves the returning of the surface area of the mining and ISR wellfield operating areas to a condition similar to pre-mining or ISR.
Reserve	That part of a mineral deposit which could be economically and legally extracted or produced at the time of the reserve determination.
Restoration	Restoration involves returning an aquifer to a condition consistent with our pre-ISR use. The restoration of wellfield can be accomplished by flushing the ore zone with native ground water and/or using reverse osmosis to remove ions to provide clean water for reinjection to flush the ore zone.

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Roll front	The configuration of a particular style of sedimentary-hosted uranium mineralization within its host rock. A term depicts a sinuous zone of uranium mineralization that is “C” shaped in cross-section.
Shut-in	A term that refers to ceasing production or the absence of production.
Shut-in royalty	A lease clause permitting the extension of a lease not held by production by payment of a per acre royalty.
Spot price	The price at which uranium may be purchased for delivery within one year.
Surety obligations	A bond, letter of credit, or financial guarantee posted by a party in favor of a beneficiary to ensure the performance of its or another party’s obligations, e.g., reclamation bonds, workers’ compensation bond, or guarantees of debt instruments.
Tailings	Waste material from a mineral processing mill after the metals and minerals of a commercial nature have been extracted; or that portion of the ore which remains after the valuable minerals have been extracted.
Uranium or uranium concentrates	U3O8 or triuranium octoxide.
U3O8	Triuranium octoxide equivalent contained in uranium concentrates, referred to as uranium concentrate.
Waste	Barren rock in a mine, or uranium in a rock formation that is too low in grade to be mined and milled at a profit.
Yellowcake	Uranium in powder form, the end-result of the ISR or conventional mining process.

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USE OF NAMES

In this Annual Report on Form 10-K, unless the context otherwise requires, the terms “we”, “us”, “our”, “WWR”, “Westwater”, “Corporation”, or the “Company” refer to Westwater Resources, Inc. and its subsidiaries. The Company changed its name from “Uranium Resources, Inc.” to “Westwater Resources, Inc.” effective August 21, 2017.

CURRENCY

The accounts of the Company are maintained in U.S. dollars. All dollar amounts referenced in this Annual Report on Form 10-K and the consolidated financial statements are stated in U.S. dollars.

CAUTIONARY NOTE REGARDING FORWARD-LOOKING STATEMENTS

With the exception of historical matters, the matters discussed in this report are forward-looking statements that involve risks and uncertainties that could cause actual results to differ materially from projections or estimates contained herein. We intend such forward-looking statements to be covered by the safe harbor provisions for forward-looking statements contained in the Private Securities Litigation Reform Act of 1995. Such forward-looking statements include, without limitation, statements regarding the adequacy of funding, liquidity, the timing or occurrence of any future drilling or production from the Company’s properties, the ability of the Company to acquire additional properties or partner with other companies, the closing of pending business combinations and the expected benefits therefrom, the Company’s anticipated cash burn rate and capital requirements. Words such as “may,” “could,” “should,” “would,” “believe,” “estimate,” “expect,” “anticipate,” “plan,” “forecast,” “potential,” “intend,” “continue,” “project” and variations of these words, comparable words and similar expressions generally indicate forward-looking statements. You are cautioned not to place undue reliance on forward-looking statements. Actual results may differ materially from those expressed or implied by these forward-looking statements. Factors that could cause actual results to differ materially from these forward-looking statements include, among others:

● the availability of capital to WWR;

● the spot price and long-term contract price of uranium and lithium;

● risks associated with our foreign operations;

● the ability of WWR to enter into and successfully close acquisitions, dispositions or other material transactions, including the pending acquisition of Alabama Graphite Corporation;

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● government regulation of the mining industry and the nuclear power industry in the United States and the Republic of Turkey;

● operating conditions at our mining projects;

● the world-wide supply and demand of uranium and lithium;

● weather conditions;

● unanticipated geological, processing, regulatory and legal or other problems we may encounter;

● currently pending or new litigation; and

● our ability to maintain and timely receive mining and other permits from regulatory agencies.

For a more detailed discussion of such risks and other important factors that could cause actual results to differ materially from those in such forward-looking statements and forward-looking information, please see “Item 1A. Risk Factors” below in this Annual Report on Form 10-K. Although we have attempted to identify important factors that could cause actual results to differ materially from those described in forward-looking statements and forward-looking information, there may be other factors that cause results not to be as anticipated, estimated or intended. There can be no assurance that these statements will prove to be accurate as actual results and future events could differ materially from those anticipated in the statements. Except as required by law, we assume no obligation to publicly update any forward-looking statements and forward-looking information, whether as a result of new information, future events or otherwise.

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PART I

ITEM 1. DESCRIPTION OF BUSINESS.

THE COMPANY

Westwater Resources, Inc. is an energy minerals exploration and development company. We presently hold exploration properties with lithium and uranium exploration potential, a uranium development property in the Republic of Turkey, as well as idled uranium production properties. We were organized in 1977 to acquire and develop uranium projects in South Texas using the ISR process. Near term uranium production potential is now centered on our Temrezli ISR project in Turkey. WWR also controls extensive exploration properties in Turkey under eight exploration and operating licenses covering approximately 39,000 acres with numerous exploration targets in Turkey, including the potential satellite Sefaatli project, which is 30 miles southwest of the Temrezli project. We have historically produced uranium by ISR methods in the state of Texas where we currently have ISR projects and two licensed processing facilities. We also have approximately 188,700 acres of mineral holdings in the prolific Grants Mineral Belt of the state of New Mexico, and 11,000 acres in the South Texas uranium province. WWR acquired these properties over the past 25 years along with an extensive information database of historic drill-hole logs and analysis. WWR ceased uranium production in 2009 and none of WWR’s properties are currently in production. As of March 1, 2018, we had 30 employees.

During 2016 and 2017, we developed a lithium focus with dominant land positions in highly prospective basins in Nevada and Utah. Our focus is on developing low cost lithium brines.

OUR STRATEGY

Our vision is to become the leading developer and producer of energy minerals, particularly lithium and uranium. Our strategy is to build value for stockholders by advancing our projects towards production when economics allow, while prudently managing our cash and liquidity position for financial flexibility. Our lithium business in Nevada and Utah involves exploration for low cost brine resources with the intent of developing them for production. In Turkey, our focus is on advancing near-term production of the Temrezli project with construction for the project anticipated to begin when the uranium market improves, which is expected to occur in the next two to five years, subject to the receipt of permits, land access and project financing. Our Rosita processing facility in South Texas may be used in the development of the Temrezli project as we plan on relocating key components of the Rosita processing facility from Texas to Turkey for use at the Temrezli project. In Texas, our focus is on fulfilling our environmental obligations with proactive restoration of legacy wellfields while maintaining our processing facilities on standby for potential operating/processing agreements. In New Mexico, we continue to assess the potential for the development of our larger scale projects on a stand-alone basis or with partners. At any time we may have acquisition or partnering opportunities in various stages of active review, including, for example, our engagement of consultants and advisors to analyze particular opportunities, analysis of technical, financial and other confidential information, submissions of indications of interest, participation in preliminary discussions and negotiations and involvement as a bidder in competitive processes.

Our pipeline of projects is prioritized as near-term, mid-term and long-term projects with a goal of achieving sustainable production over time with both lithium and uranium projects so as to take advantage of rising and/or high price environments for both of these minerals. Amidst the prevailing low uranium price environment, we continue to balance cash conservation with maintaining readiness to fast track resumption of production at such time as uranium prices show sufficient improvement. We continually adjust near-term and long-term business priorities in accordance with market conditions.

RECENT CORPORATE DEVELOPMENTS

Agreement to Acquire Alabama Graphite

On December 13, 2017, the Company entered into an arrangement agreement to acquire all of the outstanding common shares of Alabama Graphite Corp. (“Alabama Graphite”) in an all-stock acquisition. Upon completion of the acquisition, former Alabama Graphite shareholders would own approximately 29.4% of the outstanding shares of the combined company based on the number of WWR and Alabama Graphite common shares outstanding as of February 26, 2018. The Westwater Board of Directors expects the acquisition to provide significant strategic and financial benefits to the Company’s stockholders, including participation in the value chain of critical minerals for the high growth battery market, operational efficiencies and improved access to capital. Closing of the acquisition remains subject to various conditions, including approval by AGC’s and the Company’s respective stockholders and approval by the Supreme Court of British Columbia.

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Lithium Business Expansion

On June 20, 2017, the Company acquired its third lithium exploration project, through the staking of 9,270 acres of federal placer mining claims within the Railroad Valley of central Nevada. The Railroad Valley Project is located approximately 75 miles west of Ely, Nevada.

Columbus Basin Data Review and Exploration Drilling

On April 5, 2017, the Company announced that its independent geophysical consultant has completed the review, integration and reinterpretation of historical geophysical survey data acquired by the Company and covering its Columbus Basin lithium brine exploration project in Nevada. Among other things, the results of the work indicated that the depth of the Columbus Salt Marsh basin is greater than previously anticipated and identified certain targets for lithium brine exploration. In July 2017, the Company began a Phase-1 exploration drilling program at the Columbus Basin project.

On October 31, 2017, the Company announced that it has completed the Phase 1 exploration project at this project and reported the following results:

● Three core holes were completed for a total of 3,870 ft. of drilling.

● The maximum drilled depth was 1,680 ft.

● Fluids with high total dissolved solids (TDS) were identified in all three holes.

● In-house laboratory work performed at its Kingsville, Texas facility returned lithium concentrations of up to 43 parts per million (ppm) and boron concentrations of up to 173 ppm.

Planning is underway for a Phase 2 exploration program at the Project. As part of the Phase 2 program, Westwater has filed a Notice of Intent to drill in the Nina claim block and is evaluating the Phase 1 results and the results of drilling by Caeneus Minerals Ltd. on nearby lithium properties.

Sal Rica Exploration Planning

A brine sampling program at the Sal Rica Project was designed and implemented to infill previous shallow aquifer sampling completed by Mesa Exploration Corp. in 2016. The resultant combination of the new Westwater data and the existing Mesa Exploration Corp. data now provide shallow aquifer lithium concentration data on variable 1 to 2 mile centers, depending on site accessibility, across the entirety of the 13,260 acre project area.

In addition to the recent groundwater sampling event, Westwater has also completed new geophysical interpretations of the Sal Rica project area. This data is being integrated into a conceptual model of the exploration target, and will guide the ongoing planning of a drilling and hydrogeologic characterization program to further expand and define the shallow, lithium bearing, brine aquifer. So far this work has outlined a strong lithium brine anomaly that covers an area of over twenty (20) square miles, with lithium values up to 100 ppm, all at shallow depths.

Westwater has commenced the permitting process with the U.S. Bureau of Land Management (“BLM”), and the State of Utah, to field an exploration program that optimizes project access and limits environmental disturbance, minimizes cost, and maximizes overall data quality.

Option Agreement for Lithium Brine Claims

On March 24, 2017, the Company’s wholly owned subsidiary Lithium Holdings Nevada LLC entered into an option agreement to purchase a block of unpatented placer mining claims covering an area of approximately 3,000 acres within the Columbus Salt Marsh area of Esmeralda County, Nevada. The claims adjoin a portion of the Company’s current property holdings at its Columbus Basin project, expanding the project area within the basin to approximately 14,200 acres. The Company has the right to conduct exploration activities on the claims during the one-year option period. Under the option agreement, the Company may acquire the mineral property claims on or before March 24, 2018 in exchange for 200,000 shares of WWR common stock and a 1% net smelter return royalty on the claims.

Equity Financings

Confidentially Marketed Public Offering

On January 19, 2017, the Company completed a registered public offering for net proceeds of $8.9 million. The Company sold 1,399,140 shares of common stock at a price of $2.01 per share and 3,426,731 pre-funded warrants at a price of $2.00 per warrant. The warrants had an exercise price of $0.01. All of the pre-funded warrants have been exercised.

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Registered Direct Offering

On February 16, 2017, the Company completed a registered direct offering for net proceeds of $4.5 million with Aspire Capital whereby Aspire Capital purchased 2,100,000 shares of common stock at a price of $1.58 and 748,101 pre-funded common stock purchase warrants at a price of $1.57. The warrants had an exercise price of $0.01 per share and a term of three years. All of the pre-funded warrants have been exercised.

Controlled Equity Offering Sales Agreement with Cantor Fitzgerald (“Cantor”)

On April 14, 2017, the Company entered into an at-the-market offering (the “ATM Offering”) with Cantor acting as sales agent. Under the ATM Offering, the Company may from time to time sell shares of its common stock having an aggregate offering amount up to $30.0 million in “at-the-market” offerings, which shares are registered under a registration statement on Form S-3, which was declared effective on March 9, 2017. The Company pays Cantor a commission equal to 2.5% of the gross proceeds from the sale of any shares pursuant to the ATM Offering. As of March 1, 2018, the Company had sold 812,723 shares of common stock for net proceeds of $1.2 million under the ATM Offering. As a result, the Company had approximately $28.8 million remaining available for future sales under the ATM Offering. The Company’s previous ATM Offering with BTIG LLC was fully utilized as of December 31, 2016.

Common Stock Purchase Agreement (“CSPA”) with Aspire Capital

On September 25, 2017, the Company entered into the CSPA with Aspire Capital to place up to $22.0 million in the aggregate of the Company’s common stock on an ongoing basis when required by the Company over a term of 30 months. The Company will control the timing and amount of sales to Aspire Capital, and at a price based on market prices at that time. As consideration for Aspire Capital entering into the purchase agreement, the Company issued 880,000 shares of its common stock to Aspire Capital. The shares of common stock subject to the CSPA were registered pursuant to the Company’s effective shelf registration statement on Form S-3. The parties terminated the April 8, 2016 CSPA with Aspire Capital upon entering into the September 25, 2017 CSPA.

On September 27, 2017, pursuant to the CSPA and after satisfaction of certain commencement conditions, Aspire Capital made an initial purchase of 1,428,571 shares of common stock for which the Company received net proceeds of $2.0 million. Additionally, on December 14, 2017, Aspire Capital purchased 150,000 shares of common stock for which the Company received net proceeds of $0.2 million. There were no other sales of common stock pursuant to the CSPA and as of March 1, 2018, $19.8 million of the aggregate $22.0 million remained available for future sales under the CSPA.

Laramide Asset Sale

On January 5, 2017, Laramide Resources Ltd. (“Laramide”) and the Company closed the sale of the Company’s wholly-owned subsidiary Hydro Resources, Inc., which held the Churchrock and Crownpoint projects in New Mexico, pursuant to a Share Purchase Agreement (the “Laramide SPA”). Under the terms of the Laramide SPA, as amended on December 5, 2016, the Company received the following consideration:

● $2.5 million in cash, of which $250,000 was paid in advance on October 21, 2016;

● $500,000 of Laramide common stock and warrants; and

● a $5.0 million promissory note, secured by a mortgage over the projects. The note has a three-year term and carries an initial interest rate of 5% which then increases to 10% upon Laramide’s decision regarding commercial production at the Churchrock project. Principal payments of approximately $1.5 million are due and payable on January 5 in each of 2018, 2019 and $2.0 million on January 5, 2020. Interest is payable on a quarterly basis, provided however that no interest will be payable prior to the first principal payment in 2018. Laramide will have the right to satisfy up to half of each of these payments by delivering shares of its common stock to the Company, which shares will be valued by reference to the VWAP for Laramide’s common stock for the 20 trading days before the respective anniversary of January 5, on which each payment is due.

Laramide made the first required principal payment on the promissory note in January 2018, consisting of $750,000 in cash and the issuance of 1,982,483 of Laramide’s common shares.

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RCF Loan Retirement

On February 9, 2017, the Company repaid $5.5 million of principal plus accrued unpaid interest in cash to retire all of the obligations remaining under that certain loan agreement dated November 13, 2013 by and among the Company, certain of its subsidiaries and Resource Capital Fund V L.P. (“RCF”). In addition, on July 31, 2017, the Company and RCF terminated the Stockholders’ Agreement dated March 1, 2012, pursuant to which RCF had certain participation and Board rights.

OVERVIEW OF THE LITHIUM INDUSTRY

The primary use for lithium is a key ingredient in rechargeable batteries for electronic devices and electric vehicles. Lithium ion batteries, as they are known, have been adopted as the standard method of powering electronic devices such as smart phones and small, portable computers for some time, but it is the transportation market that is expected to drive growth for the next decade. Growth in consumption of lithium is expected to average over 6% annually between now and 2025, according to CRU International Limited, with the transportation sector accounting for much of this growth. This major component is expected to rise from 20% to 39% of total demand over the next seven years.

At the same time, lithium prices have risen in response to increased demand. Lithium carbonate is one form used for battery manufacturing, and prices have risen from $5,792 per metric ton in 2016 to $7,300 per metric ton in just over a year. For lithium hydroxide, a second form of the material, prices have risen from $6,974 per metric ton to over $23,000 per metric ton during the same period.

Our lithium business objectives are to discover and produce lithium from lithium salts hosted in brines. This production method is typically the lowest cost type of lithium production. While the technologies are well known in some respects, it takes time for deposits to be discovered and developed, which should result in a supply deficit over the next few years. Expected higher prices will encourage investment in the sector and bring new sources of production online over time. CRU International Limited expects long term lithium prices to stabilize at approximately $6,400 per metric ton and $9,400 per metric ton for lithium carbonate and lithium hydroxide, respectively. These are considerably higher than the historic prices for these products.

Westwater is targeting exploration and development of lithium brines because they are characteristically in the lowest operating cost quartile of production, and would be more likely to be profitable in the markets described above.

OVERVIEW OF THE URANIUM INDUSTRY

The only significant commercial use for uranium is as a fuel for nuclear power plants for the generation of electricity. According to the World Nuclear Association (“WNA”), as of January 2017, there were 448 nuclear reactors operable worldwide, up from 441 the prior year. Annual requirements for uranium amount to about 138 million pounds of uranium. Thirty countries utilized nuclear power in 2017. In addition, the WNA lists 61 reactors under construction, 164 being planned and 347 being proposed.

While global nuclear power generation is expected to drive increased demand through 2030, especially in China, Russia, India and South Korea, UxC Consulting projects continued oversupply and low uncovered demand over the near-to-medium term due to higher inventory levels at utilities. During 2017, term contracting was weak and focused on shorter period mid-term contracts. This restrained the spot market as discretionary buying was also weak. UxC projects that global nuclear power generation will expand to 518 reactors in 36 countries by 2030.

Worldwide uranium production or primary supply in 2017 is estimated by UxC Consulting in its Q4 2017 report at 151 million pounds of U₃O₈. This is compared with 160 million pounds of primary supply in 2016. Total production in 2017 is expected to total 139 million pounds. The reduction is primarily due to the suspension of Cameco’s majority-owned McArthur River/Key Lake project in Canada and a cutback at New AREVA’s SOMAIR project in Niger.

Spot prices rose from $21.00 per pound in January 2005 to a high of $136.00 per pound in June 2007 in anticipation of sharply higher projected demand as a result of a resurgence in nuclear power and the depletion or unavailability of secondary supplies. The sharp price increase was driven in part by high levels of buying by utility companies, which resulted in most utilities covering their requirements through 2009. A decrease in near-term utility demand coupled with rising levels of supplies from producers and traders led to downward pressure on uranium prices since the third quarter of 2007. A rebound in uranium prices in conjunction with a recovery in commodities in 2010 was curtailed by the Fukushima disaster in Japan in 2011.

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In 2017, the average weekly spot price of uranium was $22.06 per pound compared with $26.42 in 2016 and $36.83 per pound in 2015. In 2017, the weekly spot price of uranium reached a high of $26.50 per pound in February and again in December while the low for the year was $19.25 per pound in May. The year end 2017 spot price was $23.75 per pound.

Some analysts project that uranium prices may have bottomed and expect gradually recovering uranium prices from a supply deficit as uranium market fundamentals for supply and demand improve over time. Secondary supply inventories continue to weigh on the uranium market in the near term but are expected to reduce from depleted government inventories and a rebalancing of the enrichment sector, according to UxC. Demand for uranium is expected to improve from an increase of nuclear power generation in China and other countries.

COMPETITION

There is global competition for lithium and uranium properties, capital, customers and the employment and retention of qualified personnel. We compete with multiple exploration companies for both properties as well as skilled personnel. In the production and marketing of lithium and uranium, there are a number of producing entities globally, some of which are government controlled and several of which are significantly larger and better capitalized than we are. Several of these organizations also have substantially greater financial, technical, manufacturing and distribution resources than we have.

Our future uranium production will also compete with uranium from secondary supplies, including the sale of uranium inventory held by the U.S. Department of Energy. In addition, there are numerous entities in the market that compete with us for properties and operate ISR facilities. If we are unable to successfully compete for properties, capital, customers or employees or with alternative uranium sources, it could have a materially adverse effect on our results of operations.

With respect to sales of lithium and uranium, the Company competes primarily based on price. We will market lithium directly to users of the product, and uranium to utilities and commodity brokers. We are in direct competition with supplies available from various sources worldwide. We believe we compete with multiple lithium exploration and development companies, as well as operating uranium companies.

OVERVIEW OF WESTWATER RESOURCES’ PROJECTS

Lithium Exploration Targets

During 2016, we commenced with a program to acquire and explore lithium-enriched brine targets in the western United States. As a consequence of our in-house geological reconnaissance program we identified three prospective project areas for which we have acquired mineral rights: the Columbus Basin project in western Nevada, the Railroad Valley project in east-central Nevada and the Sal Rica Project in northwestern Utah.

Columbus Basin Project

Our Columbus Basin project is located in western Nevada and is comprised of two blocks of unpatented placer claims that we staked in July and September of 2016. These claims, which are owned by the Company, cover portions of a closed drainage basin that has geological characteristics that may be permissive for hosting lithium-enriched brines. Our exploration efforts on the project thus far have included reconnaissance-scale and detailed geochemical sampling, and the completion of three exploration drill holes. The Columbus Basin project encompasses approximately 14,200 acres, split into two significant blocks of federal placer mineral claims, and a third contiguous block for which rights were acquired through an option to purchase.

Railroad Valley Project

The Railroad Valley project is located in east-central Nevada, approximately 60 miles southwest of the town of Ely and 240 miles southeast of the city of Reno. The Railroad Valley, which is one of the largest closed basins in the State of Nevada, is also the site of the largest oil production in Nevada. Westwater Resources staff carried out extensive geochemical sampling within the Railroad Valley drainage basin and identified an area on the western flank of the basin that is host to a strong and wide-spread zone of anomalous lithium values hosted in basin-fill sediments. The Railroad Valley project encompasses approximately 9,270 acres of federal placer mineral claims.

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Sal Rica Project

Our Sal Rica project is situated in the area of a closed drainage basin that was once part of the Great Salt Lake/Lake Bonneville area of western Utah. We hold a large group of unpatented placer claims that we acquired in part from Mesa Exploration and other placer claims that we staked in 2016. The project area was explored previously by Quintana Petroleum for potash-enriched brines, and as part of their shallow drilling program they identified anomalous levels of lithium-enriched brines at depths of less than 50 feet from the surface. Our activities at the Sal Rica project thus far have been limited to geologic reconnaissance and geochemical characterization sampling. The Sal Rica project encompasses approximately 13,260 acres of federal placer mineral claims.

Uranium Projects

Turkey

In Turkey, WWR controls extensive exploration properties under eight exploration and operating licenses covering approximately 39,000 acres with numerous exploration targets, including the potential satellite Sefaatli project, which is 30 miles southwest of the Temrezli project. The project area enjoys year-round accessibility via paved roads and a number of gravel tracks and trails. Sparsely populated, but with access to major infrastructure such as water and power, the area is gently undulating. The majority of the project area is owned by local families who work the land for grain production.

Temrezli Project.

The Temrezli project is wholly owned and operated by Westwater, and was acquired by the Company from Anatolia Energy Limited (“Anatolia”) in 2015. The Company holds three (3) operating licenses encompassing approximately 6,850 acres. The Temrezli project is situated in central Turkey, approximately 150 miles east of the national capital of Ankara. Uranium mineralization was first discovered in the area of the project by the Uranium Division of Turkey’s General Directorate of Mineral Research & Exploration (“MTA”) of the Ministry of Energy and Natural Resources in the early 1980s. MTA continued to explore the region for the next 10 years. Following a change to the Turkish Mining Law in 2004 the private sector has been able to explore for radioactive substances. Anatolia Energy, through its subsidiary Adur Madencilik Ltd. commenced exploration at the Temrezli project in 2010 and using its extensive technological experience and expertise, re-evaluated and confirmed the MTA’s findings. The uranium mineralization is considered to be epigenetic and related to strata controlled redox boundaries influenced by permeability changes and/or strata bound reductants such as disseminated organic materials in fine grained rocks and iron sulfides.

After extensive analysis and other technical work, Anatolia released a preliminary feasibility study in February 2015 indicating cash operating costs of $16.89 per pound U₃O₈ and all-in operating costs of approximately $30.17 per pound U₃O₈. Technical work continues to refine the work plan for our properties in the Republic of Turkey at the field location and in our offices there, as well as our office in Denver.

Şefaatli Project.

The Şefaatli project area contains the region’s second most significant occurrence of uranium mineralization. In Şefaatli area, the Company was granted with 2 exploration licenses and 1 operation license covering an area of approximately 25,100 acres. The Şefaatli project is located approximately 30 miles southwest of the Temrezli project.

Texas

In Texas, WWR has the Kingsville Dome and Rosita licensed processing facilities and approximately 11,000 acres of prospective ISR projects and historical production assets. These wellfields and the processing facilities are on standby for a restart of production when there is a sustained improvement in the uranium market.

Key operational elements of WWR’s plan for its Texas properties include (1) positioning the Company to return to sustainable production by continuing to evaluate potential brownfield and greenfield exploration opportunities and evaluating synergistic opportunities from existing resources held by other entities; and (2) continuing reclamation activities in South Texas in accordance with the Company’s existing agreements and regulatory requirements.

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New Mexico

In New Mexico, the Company controls minerals rights encompassing approximately 188,700 acres in the west-central part of the State. WWR holds substantial non-reserve mineralized material at its properties in the prolific Grants Mineral Belt in New Mexico, which holds one of the largest known concentrations of sandstone-hosted uranium deposits in the world.

THE ISR PROCESS

The ISR process is dramatically different from conventional mining techniques. The ISR technique avoids the movement and milling of significant quantities of rock and ore and also avoids the creation of mill tailing waste associated with more traditional mining methods. It is generally more cost-effective and environmentally sensitive than conventional mining and processing. Historically, the majority of U.S. uranium production resulted from either open pit surface mines or underground mining.

The ISR process was initially developed for the production of uranium in the mid-1960s, and was first utilized at a commercial-scale project in South Texas in 1975. It became a routinely utilized recovery method in the South Texas uranium district by the late 1970s, where it was employed in about twenty commercial projects, including two operated by us.

In the ISR process, groundwater fortified with oxygen and carbon dioxide is pumped into a permeable ore body within a wellfield, causing the uranium contained in the ore to dissolve. A wellfield consists of a series of injection wells, production (extraction) wells and monitoring wells drilled in specified patterns. Wellfield pattern is crucial to minimizing costs and maximizing efficiencies of production. The resulting solutions from the wellfields are pumped to the surface, where the uranium-bearing water is circulated through an ion exchange column, and uranium is precipitated from the fluid onto resin beads. The uranium-depleted fluid is then re-injected into the subsurface uranium deposit. When the ion exchange column’s resin beads are loaded with uranium, they are removed and flushed with a salt-water solution, which liberates the uranium from the beads. This process results in uranium residing in a slurry, which is then dried and packaged for shipment as a uranium concentrate. In order to achieve greater operating efficiencies and reducing capital expenditures when developing new wellfields, we employ a wellfield- specific remote ion exchange process as opposed to a central processing plant, as we had done historically. Instead of piping the solutions over long distances through large diameter pipelines, and mixing the waters of several wellfields together, each wellfield is produced using a dedicated satellite ion exchange facility. This allows ion exchange to take place at the wellfield instead of at the central plant. The satellite facilities allow recovery of uranium from each wellfield using its own native groundwater, thus avoiding the introduction of foreign mineral complexes and the attendant complications of doing so.

ENVIRONMENTAL CONSIDERATIONS AND PERMITTING

United States

Uranium and lithium extraction is regulated by the federal government, states and, in some cases, by Indian tribes. Compliance with such regulation has a material effect on the economics of our operations and the timing of project development. Our primary regulatory costs have been related to obtaining licenses and permits from federal and state agencies before the commencement of production activities, as well as the cost for maintaining compliance with licenses and permits once they have been issued. The current environmental and technical regulatory requirements for the ISR industry are well established. Many ISR projects have gone a full life cycle without any significant environmental impact. However, the regulatory process can make permitting difficult and timing unpredictable.

U.S. regulations pertaining to ISR mining continually evolve in the U.S. However, at this time we do not anticipate any adverse impact from these regulations that would be unique to our operations.

Radioactive Material License

Before commencing ISR operations in Texas and either ISR or conventional mining activity in New Mexico, we must obtain a radioactive material license. Under the federal Atomic Energy Act, the NRC has primary jurisdiction over the issuance of a radioactive material license. However, the Atomic Energy Act also allows for states with regulatory programs deemed satisfactory by NRC to take primary responsibility for issuing the radioactive material license. NRC has ceded jurisdiction for such licenses to Texas, but not to New Mexico. Such ceding of jurisdiction by NRC is hereinafter referred to as the “granting of primacy.”

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The Texas Commission of Environmental Quality (“TCEQ”) is the administrative agency with jurisdiction in Texas over the radioactive material license. For operations in New Mexico, radioactive material licensing is handled directly by the Nuclear Regulatory Commission.

See Item 2, “Properties” for the status of our radioactive material license for Texas.

Underground Injection Control (“UIC”) Permits

The federal Safe Drinking Water Act creates a nationwide regulatory program protecting groundwater. This law is administered by the United States Environmental Protection Agency (the “EPA”). However, to avoid the burden of dual federal and state regulation, the Safe Drinking Water Act allows for the UIC permits issued by states to satisfy the UIC permit required under the Safe Drinking Water Act under two conditions. First, the state’s program must have been granted primacy. Second, the EPA must have granted, upon request by the state, an aquifer exemption. The EPA may delay or decline to process the state’s application if the EPA questions the state’s jurisdiction over the ISR site.

Texas has been granted primacy for its UIC programs, and the TCEQ administers UIC permits. The TCEQ also regulates air quality and surface deposition or discharge of treated wastewater associated with the ISR process.

New Mexico has also been granted primacy for its UIC program. Properties located in “Indian Country,” as that term is defined in federal law, remain subject to the jurisdiction of the EPA. Some of our properties are located in areas that some alleged to be in Indian Country. The Navajo Nation has been determined eligible for treatment as a state, but it has not requested the grant of primacy from the EPA for uranium related UIC activity. Until the Navajo Nation has been granted primacy, ISR activities that may fall within Indian Country will require a UIC permit from the EPA. Despite some procedural differences, the substantive technical requirements of the Texas, New Mexico and EPA underground injection control programs are very similar.

See Item 2, “Properties” and Item 3, “Legal Proceedings” for a description of the status of our UIC permits in Texas and New Mexico.

Mining Permits

All uranium producing states have regulations governing the development licensing or permitting, operation and closure of conventional and in-situ recovery mines. In New Mexico, the Mining and Minerals Division of the Energy, Minerals and Natural Resources Department is responsible for issuing permits under the authority of the New Mexico Mining Act of 1978. Well established regulations specify what information is necessary to support mine permit applications and set forth a well-defined application review process. The primary focus of the agency’s review is to ensure that the proposed mine will protect the environment surrounding the mine area, comply with relevant environmental standards, and be reclaimed to a self-sustaining ecosystem or other approved post-mine land use. Application reviews require consultation with other state agencies, public notice and public hearing opportunities. In addition to mine permits, a discharge permit must be obtained from the New Mexico Environmental Department for mine facilities such as ore pads, waste rock piles and tailings impoundments.

In Texas, the TCEQ regulates uranium mining and issues the necessary license and permits. URI holds a radioactive material license which covers the Kingsville Dome, Rosita and Vasquez sites, and that license is in timely renewal. Each site has operated under a class III injection permit also issued by the TCEQ. Rosita and Vasquez permits have both been renewed in 2014. The Kingsville mining permit application was withdrawn, without prejudice to refiling, in June 2016. For additional discussion on the withdrawn permit, see Item 3 – Legal Proceedings, below. Within each area’s permit, the TCEQ also issues production area authorizations (“PAAs”). Kingsville holds three PAAs, Rosita holds four PAAs, and Vasquez holds two PAAs. Each site also has class I non-hazardous injection permits for operation of waste disposal wells on site, which are regulated by the TCEQ as well. All permits for the disposal wells are active. The disposal well permit for Kingsville is undergoing the renewal process. In addition to the required state permits, the EPA regulates the underground aquifers and requires areas with uranium mineralization to have that portion of the aquifer exempted before state mining permits are issued. The aquifer exemptions for all three Texas sites have been issued.

Other

In addition to radioactive material licenses and UIC permits, we are also required to obtain from governmental authorities a number of other permits or exemptions, such as for laboratory glassware, wastewater discharge, for land application of treated wastewater, and air emissions.

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In order for a licensee to receive final release from further radioactive material license obligations after all of its ISR and post-production reclamation have been completed, approval must be issued by the TCEQ for Texas properties along with concurrence from NRC and for properties in New Mexico by the NRC.

In addition to the costs and responsibilities associated with obtaining and maintaining permits and the regulation of production activities, we are subject to environmental laws, including but not limited to the Comprehensive Environmental Response, Compensation and Liability Act, commonly known as Superfund or CERCLA, and regulations applicable to the ownership and operation of real property in general, including, but not limited to, the potential responsibility for the activities of prior owners and operators.

Reclamation and Restoration Costs and Bonding Requirements

At the conclusion of ISR or conventional mining, a site is decommissioned and reclaimed, and each well field is restored. Restoration involves returning the aquifer to its pre-development use. Restoration can be accomplished by flushing the ore zone with native ground water and/or using reverse osmosis to remove ions, minerals and salts to provide clean water for reinjection to flush the ore zone. Reclamation involves removing evidence of surface disturbance. Decommissioning and reclamation entails dismantling and removing the structures, equipment and materials used at the site during the ISR and restoration activities.

The Company is required by the regulatory agencies in the State of Texas to obtain financial surety relating to certain of its future restoration and reclamation obligations. The Company has provided performance bonds issued for the benefit of the Company in the amount of $9.1 million to satisfy such regulatory requirements. The performance bonds relate primarily to our operations at our Kingsville Dome and Vasquez projects.

In February 2013, the Company secured a new source to satisfy its financial surety obligations for the Texas regulatory agencies. Previously, the Company had met its financial surety obligations through a combination of bank issued letters of credit (the “LOCs”) and bonds issued for the benefit of the Company. These financial surety arrangements required the Company to fully collateralize the face amount of the LOC’s and the bonds with short term investment vehicles. This requirement resulted in the Company posting $9.1 million in cash that was restricted for the purpose of collateralizing these obligations. The Company’s new financial surety arrangements are provided by Lexon Insurance Company (“Lexon”) in the form of bonds issued for the benefit of the Company. The amount of the bonds written by Lexon total approximately $9.1 million and the collateral requirements of these bonds require the Company to maintain 40% of the value of the bonds in the form of restricted cash.

We estimate that our restoration and reclamation liabilities for prior operations at the Kingsville Dome, Vasquez and Rosita sites as of December 31, 2017, are about $7.5 million, with a carrying value of $5.7 million recorded as a liability on our balance sheet as of December 31, 2017.

The Company’s financial surety obligations are reviewed and revised periodically by the Texas regulatory agencies. In New Mexico surety bonding will be required before commencement of uranium recovery operations and will be subject to annual review and revision by NRC and the State of New Mexico or the EPA.

Lithium-enriched brines

Lithium-enriched brines on public lands, which are managed by either the U.S. Bureau of Land Management or the U.S. Forest Service, in Nevada and Utah can be acquired by staking placer mining claims. Production of lithium-enriched brines in Nevada is regulated in part by the Nevada Division of Water Resources as brine is considered to be a water resource and the Nevada Bureau of Mining Regulation and Reclamation, as well as by the relevant federal land management agency in a manner similar to the requirements for a hard-rock mine.

Water Rights

Water is essential to the ISR process. It is readily available in South Texas. In Texas, water is subject to capture and we do not have to acquire water rights through a state administrative process. In New Mexico, water rights are administered through the New Mexico State Engineer and can be subject to Indian tribal jurisdictional claims. Also in New Mexico, new water rights or changes in purpose or place of use or points of diversion of existing water rights, such as those in the San Juan and Gallup Basins where our properties are located, must be obtained by permit from the State Engineer. Applications may be approved subject to conditions that govern exercise of the water rights.

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Water rights are also an essential component for the production of lithium from brine sources. In the case of Nevada, application for water rights must be submitted to the Division of Water Rights, a state agency that holds responsibility for administration of surface and ground water in the state. The state has a well-established process for application to acquire water rights and protection of existing water rights. As is the case in most of the western states, Nevada’s water rights administration includes the evaluation of applications for new water rights, the availability of groundwater within a specific locality, point(s) of diversion and use of granted water rights for beneficial use. The State of Utah has a similar water right application and administration processes, managed under the Utah Division of Water Rights.

Republic of Turkey

Mining Law

The mining industry in Turkey is regulated by the 1985 Turkish Mining Law (Law No 3213), which was amended most recently in February 2015 (“Amended Mining Law”) and regulations issued thereunder. Mining rights and minerals are exclusively owned by the state. The ownership of minerals in Turkey is not subject to the ownership of the relevant land. The government of Turkey, under the 1985 Mining Law, as amended, delegates its right to explore and operate to individuals or legal entities by issuing licenses for a determined period of time in return for the payment of a royalty. The governmental body with responsibility for implementing the 1985 Mining Law and issuing the license and permits is the General Directorate of Mining Affairs (“MIGEM”) under the Ministry of Energy and Natural Resources. The Amended Mining Law distinguishes five groups of minerals. Pursuant to this classification the royalty amount to be paid to the state differs. Uranium mining is listed under Group 4-ç. The three types of licenses granted for prospecting and operating mines under the laws of Turkey are an exploration license, an operation license and an operation permit.

Turkish Atomic Energy Authority (“TAEK”)

Projects that involve radioactive materials are regulated and controlled by TAEK. TAEK was established by Law No. 2690 to exercise the functions assigned to it by this law. ISR mining of uranium is included in these functions by Article 4(b). For projects to be considered as a nuclear facility and for operation, several licenses are required from TAEK. The licensing process moves parallel to the Environmental Impact Assessment (“EIA”) procedure. TAEK must accept a licensee as project owner in accordance with the law. Once accepted as an owner, a licensee must obtain a site license, a construction license and an operation license to operate.

Institutional Framework for Environmental Management

The lead government agency with responsibility for environmental protection in Turkey is the Ministry of Environment and Urban Planning (“MEUP”). MEUP has a coordinating role in the development and enforcement of environmental policies in Turkey. MEUP is also responsible for EIA approvals for projects.

Permits Required Prior to Construction

These permits include the Environmental Impact Assessment (from MEUP), the certification as project owner of a nuclear facility (from TAEK), a mine operating permit (from MIGEM), a site license (from TAEK), a construction license (from TAEK), land access agreements or an expropriation decision and infrastructural permits to construct power, access road, water supply well, etc.

Environmental Impact Assessment (“EIA”) Permit

The Turkish EIA permitting process can be initiated with the submission of the EIA Application Document (the “AD”) to MEUP. Once the submission is made, the AD is checked by MEUP for compliance with the mandatory AD format and the EIA regulation. If the AD is found suitable, then it is distributed to the EIA Review and Assessment Committee (“RAC”) (made up of representatives of various governmental agencies) and the date of the official Public Meeting is determined. Following MEUP’s review the AD becomes public. The date and place of the hearing is then announced in at least one local and one national newspaper. Following the public hearing, the RAC members upload their comments about the project to the electronic permitting system and the mandatory Terms of Reference (“ToR”) for the EIA report is provided by MEUP following the payment of the EIA permitting fee by the project owner. Once the mandatory ToR is received from MEUP, the project owner and its consultant are allowed a maximum of 18 months to complete the draft EIA report for RAC’s review.

Once a draft comprehensive EIA report is submitted to the MEUP the draft EIA report is checked by MEUP for compliance with the ToR and the EIA regulation. The report is reproduced and distributed to the RAC, and the RAC meeting date is decided. At this stage, the draft EIA report is open to written public comments. Based on the RAC’s decision and consideration of the public comments, the EIA permitting process is given either a “Positive” or “Negative” decision (i.e., the impacts are found acceptable or not). The EIA permitting process is finalized by the Minister’s signature.

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Mine Operating Permit

A mine operating permit must be obtained after all the permits are received prior to construction. Application will be made to MIGEM requesting the operating permit which is in line with the operating license. MIGEM will issue the permit after reviewing the application document. This permit will require an affirmative EIA certificate (or a certificate stating that an EIA is not required), land ownership permits, and the workplace opening and operation licenses. The operating permit must be obtained within three years from the effective date of the operating license. If the operating permit is not obtained within three years from the effective date of the operating license, the operating license can be maintained by additional payments that may be characterized as penalties. Operational activities must be started within one year following the operating permit date. The royalties paid to the government will also be initiated by the operating permit.

Project Owner of a Nuclear Facility

According to TAEK, the judicial entities who intend to build and operate a nuclear installation must apply to the TAEK to be recognized as owner. After the recognition of owner, any financial or administrative change in owner’s structure must be notified to TAEK in 30 days.

Site License

Once recognized as an owner, a licensee will prepare the Site Report in order to get the Site License from TAEK. The Site Report is prepared in parallel to the EIA Report. However, the review and approval of the report will be done once the affirmative EIA decision is obtained from MEUP.

The Site Report is submitted to TAEK and the decision is released to the applicant by TAEK. An affirmative notification is deemed a site license. The conditions of the license are given to the applicant as an appendix to the license. Following the receipt of the site license, licensee can proceed with the work related to site preparation, potable water supply and electricity supply, access road, and office building construction etc.

Construction License

The initial application will be submitted to TAEK with the Preliminary Safety Analysis Report. Following the assessment of the Preliminary Safety Analysis Report the Nuclear Safety Department of TAEK prepares a limited work permit evaluation report which also includes the view of the Committee. When it is established that the protection measures are adequate and that the facility can operate without harming the safety and the health of the public, the Commission will issue the limited work permit. The limited work permit requires that the construction starts in 12 months from the date of affirmative decision, otherwise the permit is lost. This period may be extended if valid reasons are submitted to TAEK.

The comments obtained during the evaluation of the Preliminary Safety Analysis Report will be incorporated into the Final Safety Analysis Report. Once this report is accepted and finalized, then the affirmative notification is issued as the construction license.

Land Access

The project area is located in privately owned agricultural lands. Surface access to these lands must be either purchased or leased from the owners. If an agreement cannot be reached, then the licensee can initiate an expropriation process. In addition, in order to use these lands in mining, the land use must be changed from agriculture to mining. This procedure requires a “Public Benefit Decision” be obtained from the Ministry of Agriculture, Food and Livestock. As a part of the procedure, a site visit will be conducted by the local department of various ministries.

Turkish Law 3213 specifies voluntary land acquisition. This is the preferred method of land acquisition. If it is demonstrated that it will not work, then the licensee can proceed with the expropriation process. An affirmative EIA decision is a prerequisite to initiate the process. The governmental body in charge of expropriation process is the Ministry for Energy and Natural Resources (“ETKB”), and more specifically the MIGEM. Application will be made to ETKB.

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Infrastructural Permits

Several permits will be required from various offices. These permits include access road permits which are obtained from the Provincial Government and the Department of Transportation, permits for the electricity transmission lines which are handled through the local electricity authority, permits for drilling and installing a water supply well which must be obtained from the State Hydraulic Works (“DSI”) and a domestic water treatment plant must be approved by MEUP prior to installation.

Permits Required Prior to Operation

During the construction period, the operational period permitting documentation and applications will be made. Prior to starting the operation, the permits required include the Trial Environmental Permit, a workplace operating license, a hazardous waste storage permit and the Operating License (from TAEK).

Operating License from TAEK

At least six months before the start of commissioning of plant components and systems, the applicant, who was granted a construction license, must apply to TAEK for a commissioning permit. Following the evaluation of documents, TAEK may grant the commissioning permit.

AVAILABLE INFORMATION

Our internet website address is www.westwaterresources.net. Our Annual Report on Form 10-K, quarterly reports on Form 10-Q, current reports on Form 8-K, and amendments to those reports filed or furnished pursuant to section 13(a) of 15(d) of the Exchange Act, are available free of charge through our website under the tab “Investor Relations” as soon as reasonably practicable after they are electronically filed with, or furnished to, the SEC. We also make available on our website copies of materials regarding our corporate governance policies and practices, including our Code of Ethics, Nominating and Governance Committee Charter, Audit Committee Charter and Compensation Committee Charter. You may read and copy any materials we file with the Securities and Exchange Commission (“SEC”) at the SEC’s Public Reference Room at 100 F Street, NE, Washington, DC 20549. You may also obtain a printed copy of the foregoing materials by sending a written request to: Westwater Resources, Inc., 6950 S. Potomac Street, Suite 300, Centennial, Colorado 80112, Attention: Information Request, or by calling 303.531.0516. The information found on our internet website is not part of this or any report filed or furnished to the SEC.

ITEM 1A. RISK FACTORS

Our business activities are subject to significant risks, including those described below. Every investor or potential investor in our securities should carefully consider these risks. If any of the described risks actually occurs, our business, financial position and results of operations could be materially adversely affected. Such risks are not the only ones we face and additional risks and uncertainties not presently known to us or that we currently deem immaterial may also affect our business.

Risks Related to Our Business

WWR is not producing any minerals at this time. As a result, we currently have no sources of operating cash. If we cannot monetize certain existing assets, partner with another company that has cash resources, find other means of generating revenue other than producing uranium or lithium and/or access additional sources of private or public capital, we may not be able to remain in business.

As a result of low uranium prices, we ceased production of uranium in 2009. We are not planning to commence production at any of our South Texas properties until we are able to acquire additional reserves or mineralized material and uranium prices recover to levels that will ensure that production, once resumed, is sustainable in the 300,000 to 500,000 pound range per year. Our ability to begin plant construction and wellfield development in Turkey and New Mexico is subject to availability of financing and activation of our permits and licenses. All of our lithium activities are highly prospective and may never generate revenue. We do not have a committed source of financing for the development of our Temrezli project. There can be no assurance that we will be able to obtain financing for this project or our other projects. Our inability to develop the Temrezli or our other properties would have a material adverse effect on our future operations.

Until we begin uranium or lithium production, we have no way to generate cash inflows unless we monetize certain of our assets or through financing activities. Our future uranium or lithium production, cash flow and income are dependent upon the results of exploration as well as our ability to bring on new, as yet unidentified wellfields and to acquire and develop additional reserves. We can provide no assurance that our properties will be placed into production or that we will be able to continue to find, develop, acquire and finance additional reserves. If we cannot monetize certain existing assets, partner with another company that has cash resources, find other means of generating revenue other than producing uranium or lithium and/or access additional sources of private or public capital, we may not be able to remain in business and holders of our securities may lose their entire investment.

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Our ability to operate will be dependent on our ability to develop our properties and then mine them at a profit sufficient to finance further mining activities and for the acquisition and development of additional properties. The volatility of uranium and lithium prices makes long-range planning uncertain and raising capital difficult.

Our ability to operate as a mining company will be dependent on our ability to develop our properties and then operate them at a profit sufficient to finance further mining activities and for the acquisition and development of additional properties. The volatility of uranium and lithium prices makes long-range planning uncertain and raising capital difficult.

Our ability to obtain positive cash flow will be dependent on developing and then mining sufficient quantities of uranium or lithium at a profit sufficient to finance our operations and for the acquisition and development of additional mining properties. Any profit will necessarily be dependent upon, and affected by, the long and short-term market prices of uranium and lithium, which are subject to significant fluctuation. For example, uranium prices have been and will continue to be affected by numerous factors beyond our control, such as, the demand for nuclear power, political and economic conditions in uranium producing and consuming countries, uranium supply from secondary sources and uranium production levels and costs of production. A significant, sustained drop in uranium or lithium prices would cause us to recognize impairment of the carrying value of our uranium or other assets.

Our foreign operations subject us to a number of significant regulatory, legal and political risks that may have a material adverse impact on our prospects, projects, financial condition and results of operations.

Our acquisition of Anatolia Energy significantly increased the importance of foreign operations to our future prospects and growth, and our foreign operations expose us to a number of risks. These risks include such things as:

● enforcement of unfamiliar or uncertain foreign real estate, mineral tenure, contract, water use, mine safety and environmental laws and policies;

● challenges to mining, processing and related permits and licenses, or to applications for permits and licenses, by or on behalf of regulatory authorities, indigenous populations, non-governmental organizations or other third parties;

● war, crime, terrorism, sabotage, civil unrest and uncertain political and economic environments;

● deterioration in relations between the United States and the foreign jurisdictions in which we operate;

● renegotiation, nullification or forced modification of existing contracts, licenses, permits, approvals, concessions or the like;

● corruption;

● challenges in overseeing employees and contractors, including the risk that our employees and independent contractors may engage in unauthorized or illegal activity;

● exchange and currency controls and fluctuations;

● limitations on foreign exchange and repatriation of earnings;

● restrictions on mineral production and price controls;

● seizure of mineral production and expropriation or nationalization of property;

● changes in legislation, including changes related to taxation, new or increased mining royalty interests, import and export regulations, foreign ownership, foreign trade and foreign investment;

● high rates of inflation; and

● labor practices and disputes.

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For example, during the fourth quarter of 2017, the United States and the Republic of Turkey each suspended all non-immigrant visa services for travel between the two countries following the arrest of U.S. consular staff in Turkey. The uncertainty surrounding the political and economic relationship between the United States and Turkey could adversely affect our ability to operate in Turkey.

In addition, we face the numerous risks as a new acquirer that our expectations may not be realized and that we may encounter unexpected problems. We continue to review Anatolia Energy’s operations in Turkey, including compliance with local laws and applicable permitting requirements. In the event we determine material noncompliance, we could face fines or restrictions on our ability to develop our projects in Turkey, which could have a material adverse effect on our prospects, projects, financial condition and results of operations.

Further, regulatory, permitting and business arrangements in foreign jurisdictions are subject to extensive laws and regulations intended to prevent improper payments, fraud, kickbacks, self-dealing and other abusive practices. These laws and regulations may restrict or prohibit a wide range of business arrangements that are commonplace in such foreign jurisdictions, and violations of such laws and regulations could result in regulatory sanctions and serious harm to our reputation. We have adopted a code of business conduct and ethics, but it is not always possible to identify and deter misconduct, and the precautions we take to detect and prevent this activity may not be effective in controlling unknown or unmanaged risks or losses or in protecting us from governmental investigations or other actions or lawsuits stemming from a failure to be in compliance with such laws or regulations. If any such actions are instituted against us, and we are not successful in defending ourselves, those actions could have a significant impact on our business, including the imposition of significant civil, criminal and administrative penalties.

The Company has no known lithium mineral reserves and it may not find any lithium and, even if it finds lithium, it may not be in economic quantities.

The Company has no known lithium mineral reserves at its Columbus Basin project, Railroad Valley project, Sal Rica project or any other property. Additionally, even if the Company finds lithium in sufficient quantities to warrant recovery, it ultimately may not be recoverable. Finally, even if any lithium is recoverable, the Company does not know whether recovery can be done at a profit. The Company’s lithium activities are highly prospective and may not result in any benefit to the Company.

If we are unable to raise additional capital, our business may fail and holders of our securities may lose their entire investment.

We had approximately $4.1 million in cash at December 31, 2017. On average, WWR expended approximately $1.0 million of cash per month during 2017, which is expected to continue during 2018. There can be no assurance that WWR will be able to obtain additional capital after it exhausts its current cash. To the extent that we raise additional capital through the sale of equity or convertible debt securities, the issuance of such securities would likely result in substantial dilution to existing holders of our securities. If we borrow money, we will have to pay interest and may also have to agree to restrictions that limit our operating flexibility.

If additional capital is not available in sufficient amounts or on a timely basis, WWR will experience liquidity problems, and WWR could face the need to significantly curtail current operations, change our planned business strategies and pursue other remedial measures. Any curtailment of business operations would have a material negative effect on operating results, the value of our outstanding stock is likely to fall, and our business may fail, causing holders of our securities to lose their entire investment.

The benefits of integrating WWR and Alabama Graphite may not be realized.

To be successful on a going forward basis, we will need to combine and integrate the operations of WWR and Alabama Graphite into one company. Integration will require substantial management attention and could detract attention from the day-to-day business of the combined company. We could encounter difficulties in the integration process, such as the need to revisit assumptions about future production, revenues, capital expenditures and operating costs, including synergies, the loss of key employees or commercial relationships or the need to address unanticipated liabilities. If we cannot integrate WWR’s and Alabama Graphite’s businesses successfully, we may fail to realize the expected benefits of our acquisition of Alabama Graphite.

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Failure to complete the acquisition of Alabama Graphite or delays in completing the acquisition could negatively affect our stock price and future business and operations.

If our acquisition of Alabama Graphite is not completed for any reason, we may be subject to a number of risks, including the following:

● we will not realize the benefits expected from the acquisition, including potential operational efficiencies and improved access to capital;

● the current market price of our common stock may reflect a market assumption that the acquisition will occur and a failure to complete the acquisition could result in a negative perception by the stock market of WWR and a resulting decline in the market price of our common stock; and

● there may be substantial disruption to our business and distraction of our management and employees from day-to-day operations because matters related to the acquisition (including integration planning) may require substantial commitments of time and resources, which could otherwise have been devoted to other opportunities that could have been beneficial to WWR.

Delays in completing the acquisition could exacerbate uncertainties concerning the effect of the acquisition, which may have an adverse effect on the business following the acquisition and could defer or detract from the realization of the benefits expected to result from the acquisition.

WWR stockholders will suffer immediate dilution to their equity and voting interests as a result of our acquisition of Alabama Graphite.

In connection with our proposed acquisition of Alabama Graphite, we will issue up to approximately 14.1 million shares of WWR common stock to Alabama Graphite shareholders. Former Alabama Graphite shareholders would own collectively approximately 29.4% of the total number of shares the combined company’s outstanding common stock and the existing stockholders of WWR would own approximately 70.6% of the outstanding common stock of the combined company; and on a fully diluted basis, former Alabama Graphite shareholders would own collectively approximately 33% of the total number of shares of the combined company’s outstanding common stock and the existing stockholders of WWR would own approximately 67% of the outstanding common stock of the combined company. Accordingly, the issuance of WWR common stock to Alabama Graphite shareholders would have the effect of reducing the percentage of equity and voting interest held by each of WWR’s existing stockholders. Consequently, WWR stockholders as a group would have less influence over the management and policies of the combined company after the acquisition than they currently exercise.

Certain of our mineral properties may be subject to defects in title and we are at risk of loss of ownership.

Many of our mining properties are unpatented mining claims to which we have only possessory title. The validity of unpatented mining claims is often uncertain and such validity is always subject to contest. Unpatented mining claims are generally considered subject to greater title risk than patented mining claims or other real property interests that are owned in fee simple. Because unpatented mining claims are self-initiated and self-maintained, they possess some unique vulnerabilities not associated with other types of property interests. It is impossible to ascertain the validity of unpatented mining claims from public real property records, and, therefore, it can be difficult or impossible to confirm that all of the requisite steps have been followed for location, perfection and maintenance of an unpatented mining claim. The present status of our unpatented mining claims located on public lands allows us the exclusive right to remove locatable minerals, such as uranium and lithium. We are also allowed to use the surface of the land solely for purposes related to mining and processing the mineral-bearing ores. However, legal ownership of the public land remains with the federal government. We remain at risk that the mining claims may be lost either to the federal government or to rival private claimants due to failure to comply with statutory requirements. In addition, we may not have, or may not be able to obtain, all necessary surface rights to develop a property.

We may incur significant costs related to defending the title to our properties. A successful claim contesting our title to a property may cause us to compensate other persons or perhaps reduce our interest in the affected property or lose our rights to explore and develop that property. This could result in us not being compensated for our prior expenditures relating to the property.

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Exploration and development of uranium and lithium properties are risky and subject to great uncertainties.

The exploration for and development of uranium and lithium deposits involves significant risks. It is impossible to ensure that the current and future exploration programs on our existing properties will establish reserves. Whether an ore body will be commercially viable depends on a number of factors, including, but not limited to: the particular attributes of the deposit, such as size, grade and proximity to infrastructure; uranium and lithium prices, which cannot be predicted and which have been highly volatile in the past; mining, processing and transportation costs; perceived levels of political risk and the willingness of lenders and investors to provide project financing; availability of labor, labor costs and possible labor strikes; availability of drilling rigs; and governmental regulations, including, without limitation, regulations relating to prices, taxes, royalties, land tenure, land use, importing and exporting materials, foreign exchange, environmental protection, employment, worker safety, transportation, and reclamation and closure obligations. Most exploration projects do not result in the discovery of commercially mineable deposits of minerals and there can be no assurance that any of our exploration stage properties will be commercially mineable or can be brought into production.

We may enter into acquisitions, dispositions or other material transactions at any time.

We are regularly engaged in a review of opportunities to acquire or dispose of properties, to partner with other companies on projects or to acquire or merge with companies. We currently, and generally at any time, have such opportunities in various stages of active review, including, for example, our engagement of consultants and advisors to analyze particular opportunities, technical, financial and other confidential information, submission of indications of interest and participation in discussions or negotiations for acquisitions or dispositions. Any such acquisition or disposition could be material to us. We could issue common stock or incur additional indebtedness to fund our acquisitions. Issuances of common stock may dilute existing holders of our securities. In addition, any such acquisition, disposition or other transaction may have other transaction specific risks associated with it, including risks related to the completion of the transaction, the project or the jurisdictions in which the project is located. We could enter into one or more acquisitions, dispositions or other transactions at any time.

The developments at the Fukushima Daiichi Nuclear Power Plant in Japan continue to have a negative impact on the uranium markets and public acceptance of nuclear energy is uncertain.

The developments at the Fukushima Daiichi Nuclear Power Plant following the earthquake and tsunami that struck parts of Japan in March 2011 created heightened concerns regarding the safety of nuclear power plants and the ability to safeguard the material used to fuel nuclear power plants. The impact on the perception of the safety of nuclear power resulting from this event may cause increased volatility of uranium prices in the near to mid-term as well as uncertainty involving the continued use and expansion of nuclear power in certain countries. A reduction in the current or the future generation of electricity from nuclear power could result in a reduced requirement for uranium to fuel nuclear power plants which may negatively impact WWR in the future.

Maintaining the demand for uranium at current levels and future growth in demand will depend upon acceptance of nuclear technology as a means of generating electricity. The developments at the Fukushima Daiichi Nuclear Power Plant may affect public acceptance of nuclear technology. Lack of public acceptance of nuclear technology would adversely affect the demand for nuclear power and potentially increase the regulation of the nuclear power industry.

The only significant market for uranium is nuclear power plants world-wide, and there are a limited number of customers; the nuclear power industry continues to experience an overproduction of uranium.

We are dependent on a limited number of electric utilities that buy uranium for nuclear power plants. Because of the limited market for uranium, a reduction in purchases of newly produced uranium by electric utilities for any reason (such as plant closings) would adversely affect the viability of our business.

Since 2011, the nuclear power industry continues to experience an overproduction of uranium along with high inventories of uranium in various stages of production as a fuel source. These factors impact our position in the market and can adversely impact our business.

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The price of alternative energy sources affects the demand for and price of uranium.

The attractiveness of uranium as an alternative fuel to generate electricity may be dependent on the relative prices of oil, gas, coal and hydro-electricity and the possibility of developing other low-cost sources of energy. If the prices of alternative energy sources decrease or new low-cost alternative energy sources are developed, the demand for uranium could decrease, which may result in a decrease in the price of uranium.

Because of the unique difficulties and uncertainties inherent in new mineral exploration ventures, the Company’s lithium exploration activities face a high risk of business failure.

Potential investors should be aware of the difficulties normally encountered by new mineral exploration ventures and the high rate of failure of such ventures. The likelihood of success of the Company’s lithium exploration activities must be considered in light of the potential problems, expenses, difficulties, complications and delays encountered in connection with the exploration of new mineral properties. These potential problems include, but are not limited to, unanticipated problems relating to exploration and additional costs and expenses that may exceed current estimates. The expenditures to be made by the Company in the exploration of its new lithium claims may not result in the discovery of lithium deposits. Problems such as unusual or unexpected formations and other conditions are involved in new mineral exploration and often result in unsuccessful exploration efforts. If the results of the Company’s new exploration ventures do not reveal viable commercial mineralization, it may decide to abandon its claims. If this happens, the Company will not benefit from any of the expenditures it will incur in pursuing the claims.

The Company’s experience in uranium exploration may not apply to its plans for lithium exploration or development.

Although the Company and the members of its management team have significant experience in uranium exploration and development that appears to be synergistic with lithium exploration and development, neither the Company nor any member of its management team has directly engaged in the exploration for or development of lithium deposits. In particular, the Company believes there are similarities between the exploration for and development of lithium brines and the ISR of uranium, but it may not have sufficiently detailed expertise to effectively explore for and develop lithium deposits. The Company’s lack of specific lithium experience may lead it to fail to realize the anticipated benefits of its lithium exploration and development activities and may adversely affect its financial condition and results of operations. In addition, the Company may need to hire employees or retain consultants with the requisite experience in lithium exploration and development that are not currently anticipated in the near-term.

Volatility in lithium prices may make it commercially infeasible for the Company to develop its claims and may result in the Company not receiving an adequate return on invested capital.

The Company’s lithium exploration and development activities may be significantly adversely affected by volatility in the price of lithium. Mineral prices fluctuate widely and are affected by numerous factors beyond its control such as global and regional supply and demand, interest rates, exchange rates, inflation or deflation, fluctuation in the value of the United States dollar and foreign currencies, and the political and economic conditions of mineral-producing countries throughout the world. The exact effect of these factors cannot be accurately predicted, but the combination of these factors may result in the Company’s lithium activities not producing an adequate return on invested capital to be profitable or viable.

Our operations are each subject to environmental risks.

We are required to comply with environmental protection laws, regulations and permitting requirements in the United States and the Republic of Turkey, and we anticipate that we will be required to continue to do so in the future. We have expended significant resources, both financial and managerial, to comply with environmental protection laws, regulations and permitting requirements, and we anticipate that we will be required to continue to do so in the future. The material laws and regulations within the U.S. include the Atomic Energy Act, Uranium Mill Tailings Radiation Control Act of 1978, or UMTRCA, Clean Air Act, Clean Water Act, Safe Drinking Water Act, Federal Land Policy Management Act, National Park System Mining Regulations Act, the State Mined Land Reclamation Acts or State Department of Environmental Quality regulations and the Dodd-Frank Wall Street Reform and Consumer Protection Act, and the rules and regulations of the NEPA, as applicable.

We are required to comply with the Atomic Energy Act, as amended by UMTRCA, by applying for and maintaining an operating license from the NRC and the State of Texas. Uranium operations must conform to the terms of such licenses, which include provisions for protection of human health and the environment from endangerment due to radioactive materials. The licenses encompass protective measures consistent with the Clean Air Act and the Clean Water Act. Mining operations may be subject to other laws administered by the USEPA and other agencies.

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The uranium industry is subject not only to the worker health and safety and environmental risks associated with all mining businesses, but also to additional risks uniquely associated with uranium ISR, mining and milling. 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 ISR, mining or milling, the disposition of wastes, the decommissioning and reclamation of exploration, mining and ISR 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, regulation or policy 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, generally, is 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, 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 or stricter interpretation of existing laws, may necessitate significant capital outlays, may materially affect our results of operations and business or may cause material changes or delays our intended activities.

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. Environmental assessments of proposed projects carry a heightened degree of responsibility for companies and directors, officers and employees. We cannot provide assurance that we will be able to obtain or maintain all necessary permits that may be required to continue our operation or exploration of our properties or, if feasible, to commence development, construction or operation of mining facilities at such properties on terms which enable operations to be conducted at economically justifiable costs. If we are unable to obtain or maintain permits or water rights for development of our properties or otherwise fail to manage adequately future environmental issues, our operations could be materially and adversely affected.

Closure and remediation costs for environmental liabilities may exceed the provisions we have made.

Natural resource companies are required to close their operations and rehabilitate the lands in accordance with a variety of environmental laws and regulations. Estimates of the total ultimate closure and rehabilitation costs for extractive operations are significant and based principally on current legal and regulatory requirements and closure plans that may change materially. Any underestimated or unanticipated rehabilitation costs could materially affect our financial position, results of operations and cash flows. Environmental liabilities are accrued when they become known, are probable and can be reasonably estimated. Whenever a previously unrecognized remediation liability becomes known, or a previously estimated reclamation cost is increased, the amount of that liability and additional cost will be recorded at that time and could materially reduce our consolidated net income in the related period.

The laws and regulations governing closure and remediation in a particular jurisdiction are subject to review at any time and may be amended to impose additional requirements and conditions which may cause our provisions for environmental liabilities to be underestimated and could materially affect our financial position or results of operations.

Because mineral exploration and development activities are inherently risky, we may be exposed to environmental liabilities and other dangers. If we are unable to maintain adequate insurance, or liabilities exceed the limits of our insurance policies, we may be unable to continue operations.

The business of mineral exploration and extraction involves a high degree of risk. Few properties that are explored are ultimately developed into production. Unusual or unexpected formations, formation pressures, fires, power outages, labor disruptions, flooding, explosions, cave-ins, landslides and the inability to obtain suitable or adequate machinery, equipment or labor are other risks involved in extraction operations and the conduct of exploration programs. Previous mining operations may have caused environmental damage at certain of our properties. It may be difficult or impossible to assess the extent to which such damage was caused by us or by the activities of previous operators, in which case, any indemnities and exemptions from liability may be ineffective. If any of our properties are found to have commercial quantities of minerals, we would be subject to additional risks respecting any development and production activities.

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Although we carry liability insurance with respect to our mineral exploration operations, we may become subject to liability for damage to life and property, environmental damage, cave-ins or hazards against which we cannot insure or against which we may elect not to insure because of cost or other business reasons. In addition, the insurance industry is undergoing change and premiums are being increased. If we are unable to procure adequate insurance because of cost, unavailability or otherwise, we might be forced to cease operations.

Reserve and other mineralized material calculations are estimates only, and are subject to uncertainty due to factors including the price of uranium and lithium, inherent variability of the ore and recoverability of uranium and lithium in the recovery process.

The calculation of reserves, other mineralized material tons and grades are estimates and depend upon geological interpretation and geostatistical relationships or assumptions drawn from drilling and sampling analysis, which may prove to be unpredictable. There is a degree of uncertainty attributable to the calculation of reserves and mineralized material and their corresponding grades. Until reserves and other mineralized materials are actually mined and processed, the quantity of ore and grades must be considered as an estimate only. In addition, the quantity of reserves and other mineralized materials may vary depending on the price of uranium and lithium. Any material change in the quantity of reserves, other mineralized materials, mineralization or grade may affect the economic viability of our properties.

Our inability to obtain financial surety would threaten our ability to continue in business.

Future financial surety requirements to comply with federal and state environmental and remediation requirements and to secure necessary licenses and approvals will increase significantly as future development and production occurs at certain of our sites in the United States and Turkey. The amount of the financial surety for each producing property is subject to annual review and revision by regulators. We expect that the issuer of the financial surety instruments will require us to provide cash collateral for a significant amount of the face amount of the bond to secure the obligation. In the event we are not able to raise, secure or generate sufficient funds necessary to satisfy these requirements, we will be unable to develop our sites and bring them into production, which inability will have a material adverse impact on our business and may negatively affect our ability to continue to operate.

Competition from better-capitalized companies affects prices and our ability to acquire both properties and personnel.

There is global competition for uranium and lithium properties, capital, customers and the employment and retention of qualified personnel. In the production and marketing of uranium and lithium, there are a number of producing entities, some of which are government controlled and all of which are significantly larger and better capitalized than we are. Many of these organizations also have substantially greater financial, technical, manufacturing and distribution resources than we have.

Our future uranium production will also compete with uranium recovered from the de-enrichment of highly enriched uranium obtained from the dismantlement of United States and Russian nuclear weapons and imports to the United States of uranium from the former Soviet Union and from the sale of uranium inventory held by the United States Department of Energy. In addition, there are numerous entities in the market that compete with us for properties and are attempting to become licensed to operate ISR and/or underground mining facilities. If we are unable to successfully compete for properties, capital, customers or employees or with alternative uranium sources, it could have a materially adverse effect on our results of operations.

Because we have limited capital, inherent mining risks pose a significant threat to us compared with our larger competitors.

Because we have limited capital we may be unable to withstand significant losses that can result from inherent risks associated with mining, including environmental hazards, industrial accidents, flooding, earthquake, interruptions due to weather conditions and other acts of nature which larger competitors could withstand. Such risks could result in damage to or destruction of our infrastructure and production facilities, as well as to adjacent properties, personal injury, environmental damage and processing and production delays, causing monetary losses and possible legal liability. Our business could be harmed if we lose the services of our key personnel.

Our business and mineral exploration programs depend upon our ability to employ the services of geologists, engineers and other experts. In operating our business and in order to continue our programs, we compete for the services of professionals with other mineral exploration companies and businesses. In addition, several entities have expressed an interest in hiring certain of our employees. Our ability to maintain and expand our business and continue our exploration programs may be impaired if we are unable to continue to employ or engage those parties currently providing services and expertise to us or identify and engage other qualified personnel to do so in their place. To retain key employees, we may face increased compensation costs, including potential new stock incentive grants and there can be no assurance that the incentive measures we implement will be successful in helping us retain our key personnel.

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The Company has no history of paying dividends on its common stock, and we do not anticipate paying dividends in the foreseeable future.

The Company has not previously paid dividends on its common stock. We currently anticipate that we will retain all of our available cash, if any, for use as working capital and for other general corporate purposes. Any payment of future dividends will be at the discretion of our Board of Directors and will depend upon, among other things, our earnings, financial condition, capital requirements, level of indebtedness, statutory and contractual restrictions applicable to the payment of dividends and other considerations that our Board of Directors deems relevant.

Terms of subsequent financings may adversely impact holders of our securities.

In order to finance our future production plans and working capital needs, we may have to raise funds through the issuance of equity or debt securities. Depending on the type and the terms of any financing we pursue, holders of our securities’ rights and the value of their investment in our common stock could be reduced. A financing could involve one or more types of securities including common stock, convertible debt or warrants to acquire common stock. These securities could be issued at or below the then prevailing market price for our common stock. We currently have no authorized preferred stock. In addition, if we issue secured debt securities, the holders of the debt would have a claim to our assets that would be prior to the rights of holders of our securities until the debt is paid. Interest on these debt securities would increase costs and negatively impact operating results. If the issuance of new securities results in diminished rights to holders of our common stock, the market price of our common stock could be negatively impacted.

Shareholders could be diluted if we were to use common stock to raise capital.

We may need to seek additional capital to carry our business plan. This financing could involve one or more types of securities including common stock, convertible debt or warrants to acquire common stock. These securities could be issued at or below the then prevailing market price for our common stock. Any issuance of additional shares of our common stock could be dilutive to existing holders of our securities and could adversely affect the market price of our common stock.

The effect of comprehensive U.S. tax reform legislation on WWR and its affiliates, whether adverse or favorable, is uncertain.

On December 22, 2017, President Trump signed into law the Tax Cuts and Jobs Act. Among a number of significant changes to the current U.S. federal income tax rules, the Tax Cuts and Jobs Act reduces the marginal U.S. corporate income tax rate from 35% to 21%, limits the deduction for net interest expense, shifts the United States toward a more territorial tax system, and imposes new taxes to combat erosion of the U.S. federal income tax base. The effect of the Tax Cuts and Jobs Act on WWR and its affiliates, whether adverse or favorable, is uncertain, and may not become evident for some period of time. You are urged to consult your tax advisor regarding the implications of the Tax Cuts and Jobs Act.

ITEM 1B. UNRESOLVED STAFF COMMENTS

None.

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ITEM 2. PROPERTIES

URANIUM PROCESSING FACILITIES

Kingsville Dome

Our Kingsville Dome property is located in Kleberg County and is situated on several tracts of land leased from third parties. The property is situated approximately eight miles southeast of the city of Kingsville, Texas. The project was constructed in 1987 as an up-flow uranium extraction circuit, with complete drying and packaging facilities within the recovery plant. The Kingsville Dome project produced uranium in the period 1988 through 1990, from 1996 to 1999, and most recently from 2007 through 2009. Two independent resin processing circuits and elution systems are part of the plant’s processing equipment, and it also has a single drying circuit. As currently configured, the Kingsville Dome plant has a production capacity of 800,000 pounds of U₃O₈ per year.

Uranium production at Kingsville Dome was shut down in 2009 and the plant has been in a standby status since that time. The plant has two 500 gallon per minute reverse osmosis systems for groundwater restoration. The first unit was idled in 2010 and the second unit was idled in January of 2014, when ground water restoration was completed. The plant can serve as a processing facility that can accept resin from multiple satellite facilities. In addition to the processing plant there are four satellite ion exchange systems in the project area. Each of the satellite systems is capable of processing 900 gallons per minute of uranium-bearing ISR fluids from well fields, and these satellite plants can be relocated to alternate extraction sites as needed. As is the case with the main plant, the satellite facilities have been on standby since 2009.

Rosita

Our Rosita uranium processing plant and associated well fields are located in Duval County, Texas on a 200 acre tract of land owned by the Company. The facility is located within the South Texas uranium province, about 22 miles west of the town of Alice. The plant was constructed in 1990, and was originally designed to operate as an up-flow extraction facility, in a similar manner to our Kingsville Dome plant. Resin was processed at the Rosita plant, and the recovered uranium was precipitated into slurry, which was then transported to Kingsville Dome for final drying and packaging. Production from the Rosita plant began in 1990 and continued until 1999, when it was placed on standby. In the 2007-2008 period upgrades were made to the processing equipment and additions to the facility were installed, including revisions to the elution and precipitation circuits, and the addition of a full drying system. Construction terminated when the plant was 95% complete, due to production and price declines. We anticipate that the plant will have an operating capacity of 800,000 pounds of U₃O₈ per year when the upgrades have been completed. We are in the process of evaluating a relocation of our Rosita uranium processing plant to the Temrezli project in Turkey.

One satellite ion exchange system is in place at the Rosita project, but only operated for a short period of time in 2008. Loaded resin from the Rosita satellite unit was shipped to Kingsville Dome for processing.

Vasquez

The Vasquez project is located in Duval County, Texas, a short distance northwest of the town of Hebbronville. The project is situated on a leased tract of land that is being held until final groundwater restoration has been completed. The Vasquez ISR mine was constructed in 2004. Uranium recovered from wellfields at the Vasquez project was partially processed through a satellite ion exchange system, capable of processing 1,200 gallons per minute, and with final uranium recovery was undertaken at the Kingsville Dome plant. In addition to the satellite recovery facility, there is a 500 gallon per minute reverse osmosis system that has been utilized in our groundwater restoration efforts, which were completed in January, 2014. Uranium recovery efforts at the Vasquez project took place between 2004 and 2008. Reclamation of the wellfields is in progress

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LITHIUM PROPERTIES

 

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In 2016 we acquired land positions for potential lithium development in two prospective basins for lithium brines in the western United States – the Columbus Basin Project in Nevada and the Sal Rica Project in Utah. The Columbus Basin Project is located in western Nevada, approximately 27 miles northwest of the only lithium brine production facility in the United States, the Clayton Valley/Silver Peak lithium brine operation of Albemarle Corporation, and covers an area of approximately 14,200 acres. The Sal Rica Project is comprised of approximately 13,260 acres of placer mining claims covering a prospective target for lithium-enriched brines situated in the Pilot Valley region of northwestern Utah. In 2017, we acquired one additional lithium brine exploration project – Railroad Valley – which is situated in east-central Nevada. This project is comprised of approximately 9,270 acres of placer claims owned directly by the Company.

 

Columbus Basin Project, Esmeralda County, Nevada

The Property. We staked the claims that comprise our Columbus Basin lithium brine exploration project in July and September of 2016. The project area covers an area of approximately 14,200 acres, and is comprised of 567 unpatented placer mining claims. The properties do not have any work requirements or royalty obligations attached to them, although we are required to make annual claim maintenance payments of $87,885 to the US Bureau of Land Management in order to keep the properties in good standing.

Accessibility. Our Columbus Basin project is situated in west-central Nevada, about 45 miles west of the town of Tonopah and 140 miles southeast of the city of Reno. All weather access to the project site is excellent; paved highways US-6 traverses the southwest part of our claim block and US-95 is on the eastern border of the project. A county maintained gravel road and several unmaintained trails cross the northern and western parts of the project.

An industrial rated electrical power line is present in the northern part of the project area, and mining related services are available in the nearby town of Tonopah.

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History. The area of our Columbus Basin project has been the site of exploration for borate mineralization, potash-enriched brines and placer-hosted gold mineralization intermittently since the late 1800s. The Columbus Salt Marsh was the site of prospecting and small-scale production of borate minerals during the period of 1871 to 1881, exploration for potash-enriched brines was carried out, apparently without success, in 1912 and 1913, and placer gold prospecting has been carried out in the region up to the present. We are not aware of any previous significant exploration for lithium-enriched brines on our properties.

Project Geology. The Columbus Salt Marsh, site of our Columbus Basin project, is a closed drainage basin that covers an area of approximately 370 square miles that is dominated by geologically young basin-fill and lake sediments. The region, which is located within the Walker Lane geologic province, has a complex geologic structural setting, and is bounded on its eastern and southern sides by very thick sequences of Tertiary-age volcanic rocks that are potential lithium source rocks, as indicated by the presence of clay-hosted lithium mineralization in the adjoining northwestern part of the Silver Peak Range, southwest of the project target area.

Project Activities. In 2017 Westwater advanced the geologic knowledge of the Columbus Basin project through completion of the geophysical data study, and the completion of three exploration drill holes. The results of this Phase I exploration drill program included:

● Three core holes were completed for a total of 3,870 ft. of drilling.

○	The maximum drilled depth was 1,680 ft.
○	Fluids with high total dissolved solids (TDS) were identified in all three holes.

● In-house laboratory work performed at the Company’s Kingsville, Texas facility returned lithium concentrations of up to 43 parts per million (ppm) and boron concentrations of up to 173 ppm.

WWR is currently developing a Phase 2 work program for the project to build upon the results of the 2017 drill program.

Permitting Status. Westwater currently has two approved Notices of Intent for exploration drilling at the Columbus Basin project, allowing for a total of 7 drill holes. In 2017, WWR completed three of these permitted exploration drill holes. Additionally, in order to develop potential mineral resources, WWR applied for, and was granted water rights totaling 1,528 feet per year.

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Railroad Valley Project, Nye County, Nevada

The Property. Westwater staked the Railroad Valley project in 2017 based upon reconnaissance level sampling that showed highly anomalous lithium concentrations in surface sediments. The project consists of 470 contiguous federal placer mining claims covering a total of 9,270 acres. There are no royalties or work commitments associated with the project. Annual claim maintenance fess payable to the BLM total approximately $72,850.

Accessibility. Accessibility to the Railroad Valley project area is excellent. A two-lane paved federal highway (US-6), which connects the towns of Ely (approximately 60 miles to the northeast of the project area) and Tonopah crosses the area a few miles north of the Company’s mining claim block. The immediate project area is connected to US-6 by a network of maintained and unmaintained gravel roads. Power lines to oil production and refining facilities east and northwest of the Company’s property holdings appear readily accessible.

History. There has been little, if any, known exploration for lithium-enriched brines in the Railroad Valley area. Some exploration for potash-rich brines was undertaken in the 1920s by the US Geological Survey, but this work apparently did not discover sufficient resources to justify production. The area has been the site of the most intensive petroleum exploration and production activities in Nevada. Several oil fields were discovered east and north of the Company’s properties, and these production facilities remain active.

Geology. The Railroad Valley is a large “closed” topographic and drainage basin that is bounded on the east side by a very thick sequence of Paleozoic siliciclastic and carbonate rocks, and by a large block of Tertiary-age felsic and mafic volcanic rocks on its west flank. The valley has been filled with a sequence of very young sediments, including intervals of volcanic ash and evaporites. Structural features, primarily faults and fractures, are present in the project area, as are manifestations of present-day geothermal activity. A comprehensive program of geochemical sampling by Company staff has defined a large area of strong lithium values hosted in near-surface basin-fill sediments on our claims.

Project Activities. WWR has carried out a range of geological investigations and conducted geochemical sampling throughout the entire Railroad Valley area. Geophysical data is being acquired and will be incorporated with geological data to refine the geologic understanding of the lithium-enriched brine targets in the project area.

Permitting Activities. The Company holds an approved Notice of Intent for exploration drilling operations from the BLM. An application for a dissolved minerals exploration drilling permit from the Nevada Division of Minerals will be submitted in 2018 prior to any drilling activities. An application for water rights with the Nevada Division of Water Resources is pending.

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Sal Rica Project, Box Elder County, Utah

The Property. Our Sal Rica lithium brine exploration project was acquired from Mesa Exploration Corporation in September, 2016 for a combination of shares in Westwater Resources, Inc. and cash, as well as a two percent NSR royalty, payable to Mesa Exploration, on future production from the acquired lands. The property is comprised of approximately 10,240 acres of unpatented placer mining claims that were acquired from Mesa, and an additional 3,360 acres of unpatented placer claims that we staked subsequent to the purchase from Mesa Exploration. These additional placer claims, which adjoin the lands obtained from Mesa, are not subject to production royalties. In total, we hold 663 unpatented placer claims in the project area. Annual fees payable to maintain these properties in good standing are $102,765, in the form of annual claim maintenance fees payable to the BLM. There are no other obligations to keep our properties in good standing.

Accessibility. The Sal Rica project is situated within the Pilot Valley area of northwestern Utah, approximately 25 miles north of the town of Wendover, and about 100 miles west of Salt Lake City. The project area is accessible from Wendover by maintained gravel roads that flank the east and west sides of the project area, and unmaintained trails and “two-track” roads provide access from the gravel roads to the mining claims.

An electrical line is present in the southwestern part of the project area, and it provides power to a number of local ranches.

History. The Sal Rica project area was first explored for minerals by Quintana Petroleum in the mid-1960s, who drilled a series of wide-spaced (generally ranging from 1 to 2 mile spacing) shallow holes in search of potash bearing brines hosted in near-surface aquifers. As part of their exploration program Quintana analyzed material recovered from these drill holes for a range of associated elements, including lithium. Analytical results from this work indicated the presence of anomalous lithium values ranging from 22 to 81 parts per million lithium over an area of about 42 square miles. Mesa Exploration carried out a sampling program on the property in 2016 in an effort to confirm the analytical results, and obtained sample values ranging as high as 80 parts per million lithium and averaging 66 parts per million, consistent with the historical results of Quintana’s drilling.

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Other than the Quintana and Mesa Exploration activities on the property there has been no mineral production from the project area.

Project Geology. The Sal Rica project area is situated in the Pilot Valley, a closed drainage basin that covers an area of about 130 square miles along the western margin of the Salt Lake Desert of western Utah. Regional geophysical studies carried out by the staff of the University of Utah, performed between 1957 and 1961, indicated that basin-fill sediments, as potential host rocks for lithium-enriched brines, attain a maximum depth of approximately 5,300 feet. These young and generally porous and permeable rocks were identified as potential host aquifers for lithium-enriched brines. Sampling of these uppermost rock sequences, at depths of 50 feet or less, has demonstrated the presence of anomalous levels of lithium-enriched brines.

Project Activities. We first identified the Sal Rica area as a potential target for exploration through a study of available geological and geophysical data, which was followed up by reconnaissance-scale exploration on the property, including collecting a limited number of sediment and brine samples. The results of our sampling show anomalous levels of lithium in sediments and brine sample results that are consistent with the results from the sampling programs carried out by Quintana and Mesa Exploration, and has returned lithium values in brine up to 100 ppm.

Permitting Status. Westwater Resources has applied for water rights with the Utah Division of Water Rights to facilitate production of any potential resource identified in the project area. The company is currently preparing exploration permits for 2018.

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URANIUM PROPERTIES

Temrezli Project, Yozgat Province, Republic of Turkey

The Property. We acquired the Temrezli uranium project in November 2016. We control five licenses that make up the project area which were granted by the Turkish General Directorate of Mining Affairs under the 1985 Mining Law, as amended. The granted licenses cover an area of approximately 13,490 acres. We hold these licenses through the payment of fees to the Turkish government and the fulfillment of certain physical work obligations on an annual basis. Four of the licenses are classed as “Operating Licenses”, and a change in status to “Operating License” status is pending for the remaining two licenses. Uranium production from the licenses is subject to the payment of a sliding-scale royalty, ranging from 2% to 16% depending upon the sales price of uranium, as defined by Turkish mining law. The sliding-scale royalty payments are to be made to certain agencies of the local and Turkish governments. A further 1% royalty is payable to the General Directorate of Mining Affairs, who discovered the Temrezli uranium deposit.

Accessibility. The Temrezli project is situated in the Central Anatolia Region, Sorgun District of the Yozgat Province, Republic of Turkey. The project is situated near the center of the country, approximately 150 miles east-southeast of the national capital of Ankara. The project area is located about 10 miles south of the city of Sorgun and 45 miles southeast of the provincial capital of Yozgat.

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Well maintained all-weather public highways connect Ankara with the provincial capital of Yozgat and the nearby city of Sorgun. Access to the project area from Sorgun to the general project area is provided by all-weather paved roads. A maintained dirt road connects the nearby villages of Akoluk and Mehmetbeyli and crosses the north-central part of the Temrezli project. Several unimproved dirt tracks and farm trails provide access to other parts of the project area, but these roads may become impassable for short periods of time during heavy precipitation.

Suitable sources of electrical power and water are available within the Temrezli property, and various sources of goods and services, as well as labor are readily available in the city of Sorgun, which is approximately 10 miles north of the project.

Project Activities. An extensive program of diamond core and rotary drilling has been conducted, as well as comprehensive environmental and cultural resources surveys and a wide range of metallurgical testing on uranium mineralization. The result of this extensive an complicated work was the production of a Preliminary Feasibility Study, which defines many of the important design and operating aspects of the project. These reports rely upon experts in the field of uranium development and production using methods developed over decades of work.

Since acquiring the Temrezli project we have continued the various environmental and hydrological studies required for submission of operating permit applications and undertaking further metallurgical tests. We have carried out detailed studies of the quantity and quality of the uranium mineralization at the Temrezli deposit and expect to prepare a detailed economic and operational assessment of the project. The timing of these studies is dependent upon the potential development of the Temrezli project as a future ISR uranium mine.

Project Geology. Uranium at the Temrezli project occurs as a series of generally flat lying to gently dipping tabular mineralized bodies that are hosted in medium to coarse-grained nearshore marine sandstones at depths ranging from less than 200 feet to approximately 600 feet beneath the surface. Individual mineralized zones range from a the low 100s to about 1,000 feet in length, several 10s to 100 feet in width, and about 3 to approximately 30 feet in thickness. The mineralized zones are 100 feet or more beneath the local water table.

Permitting Status. We hold permits for exploration and development drilling on the property and hydrological testing of the mineralized zones. We have collected a comprehensive suite of environmental and cultural resource data for the project area, and its immediate vicinity, to serve as the basis for the application of an Environmental Impact Assessment, which, in turn would lead to the issuance of a mine operating permit.

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Şefaatli Project, Yozgat Province, Republic of Turkey

The Property. The Şefaatli Project was acquired in November 2016. We hold three exploration licenses in the project area. These licenses cover an area of approximately 25,113 acres. Two of the licenses are in advanced exploration license status. One license is on a pending operation license status.

Accessibility. The Şefaatli project is located in the town of Şefaatli district in Yozgat Province in central Turkey. The project area is located about six miles from city of Şefaatli and 20 miles southwest of the provincial capital of Yozgat.

Well maintained all-weather public highways connect Ankara with the provincial capital of Yozgat and the nearby city of Şefaatli. Access to the properties from Şefaatli is provided by all-weather village roads. These roads may become impassable for short periods of time during heavy precipitation.

Project Activities. The Şefaatli project was first discovered by the Uranium Division of the General Directorate of Mineral Research & Exploration (“MTA”) of the Ministry of Energy and Natural Resources in the late 1980s. MTA conducted over 15,000 meters drilling during their work. The mineralized zones were discovered but the lateral extents of these zones were not identified at that time. Since that time no work was done until the property rights were transferred to Adur in 2008 and 2011. Adur completed 117 exploration and resource drill holes with a total of 11,951 meters. We expect to conduct additional drilling on the property in the future to define the resource boundaries.

Project Geology. The basement rock in the property consists of Cretaceous aged granite which is overlaid by uranium containing Eocene aged shallow marine sediments. Pliocene limestone is locally covering Eocene units. All these units are overlaid by Quaternary alluvium. Granitic intrusions are considered to be the source of the uranium. Uranium bearing lenses are formed in oxidation reduction boundaries of Eocene aged fine to coarse grained sandstone after uranium was washed and transported by ground and meteoric water.

Permitting Status. We hold permits for exploration and development drilling on the property of the mineralized zones.

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SOUTH TEXAS PROPERTIES AND EXPLORATION PROJECTS

We currently control three production properties and one exploration project in the state of Texas, all of which are located in the South Texas uranium province, an arcuate belt of sandstone-hosted uranium deposits that extends from near the Texas-Mexico border on the south to an area southeast of the city of San Antonio on the northeast. The belt parallels the present-day coast of the Gulf of Mexico, and is approximately 160 miles long and up to 35 miles in width. The Company’s Kingsville Dome, Rosita and Vasquez properties and the Butler Ranch project are all situated within this belt of known uranium deposits. The Kingsville Dome, Rosita and Vasquez properties are owned by our wholly-owned subsidiary URI, Inc. and the Butler Ranch project is owned by the Company’s wholly owned subsidiary, Uranco, Inc. The locations of the Kingsville Dome, Rosita and Vasquez production properties and the Butler Ranch project are described below.

From 1988 to 1999 we produced approximately 6.1 million pounds of U₃O₈ from the Kingsville Dome and Rosita projects, and from 2004 to 2009, Kingsville Dome, Rosita and Vasquez produced an additional 1.4 million pounds of U₃O₈.

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Kingsville Dome Project, Kleberg County, Texas:

The Property. The Kingsville Dome project is located in central Kleberg County, South Texas, approximately 35 miles southwest of the city of Corpus Christi and eight miles southeast of the town of Kingsville. The project is comprised of numerous mineral leases from private landowners, covering an area of approximately 2,434 gross and 2,227 net acres of mineral rights. The leases are held through the payment of annual rents, and the leases provide for the payment of production royalties, ranging from 6.25% to 9.375%, based upon uranium sales from the respective leases. The leases have expiration dates ranging from 2000 to 2007; however, we continue to hold most of these leases through our ongoing restoration activities. With a few minor exceptions, the leases contain clauses that permit us to extend the leases not held by production by payment of royalties ranging from $10 to $30 per acre.

Accessibility. Access to the Kingsville Dome process facility is very good, as an improved company-owned private road connects the facility with Texas Farm to Market Road 1118 about eight miles southeast of Kingsville, Texas, and about four miles east of U.S. Highway 77 at the town of Ricardo. Numerous county and ranch roads, some of which are only intermittently maintained, provide access to the entire project area.

Suitable electrical power is present at the site of the Kingsville Dome process plant, and additional power lines throughout the areas of the wellfields throughout the project area.

History. Initial production from the Kingsville Dome uranium deposit commenced in May 1988. From the onset of production until July, 1999 we produced a total of 3.5 million pounds of U₃O₈ from the project area. Production was suspended in July, 1999, due to depressed uranium prices, but it resumed in April, 2006. Production in 2006 was 94,100 pounds of U₃O₈, 338,100 pounds in 2007, 252,000 pounds in 2008 and 56,000 pounds in 2009. We have not produced any uranium at the Kingsville Dome project since 2009. The Kingsville Dome project currently contains insignificant mineralized material.

Project Geology: Uranium mineralization at the Kingsville Dome project occurs as roll-front deposits hosted in porous and permeable sandstones of the Goliad Formation, at depths ranging from 600 to 750 feet beneath the surface. The mineralization is localized along the southwestern to northern flanks of the Kingsville Dome geological feature, which also hosts oil and gas deposits in geological units that are situated well below the Goliad Formation sandstones. We do not control those oil and gas deposits.

Restoration and Reclamation. The Company completed the groundwater restoration program during 2013 and entered the required stabilization period. As a result, the Company did not incur any costs related to restoration and reclamation activities during 2017. During 2017, we conducted stability and standby care activities at the Kingsville Dome project, as required by our permits and licenses.

There are three TCEQ authorized production areas at the Kingsville Dome project. In 2012, restoration was completed within ten wellfields located in production areas 1 and 2. In 2013, URI, Inc. continued to sample and observe the wellfields in production areas 1 and 2 during a stabilization period required by TCEQ rules, and on October 15, 2013 we declared to TCEQ that groundwater restoration was complete in production areas 1 and 2. Groundwater restoration for production area 3 was conducted throughout 2013, completed in December 2013 and simultaneously placed into stability. Subject to regulatory approval, groundwater restoration is completed for the entire project. Since we began our groundwater activities in 1998, we have processed and cleaned approximately 2.6 billion gallons of groundwater at the Kingsville Dome project.

Permitting Status. A radioactive material license issued by the TCEQ is in timely renewal. On September 26, 2012, we filed the requisite application for renewal of our UIC permit, and on December 12, 2012, we filed an amendment to the application that would provide for resumption of uranium recovery activities. In June 2016, we requested to withdraw our UIC permit and resubmit at a later date. The request to withdraw was granted by the TCEQ in April 2017. As new areas are proposed for production, additional authorizations under the area permit would be required. The permit for the waste disposal well 248 (WDW248) was submitted for renewal to the TCEQ and we are in the public comment phase of the renewal process.

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Rosita Project, Duval County, Texas

The Property. The Rosita project is located in north-central Duval County Texas, about 14 miles southeast of the town of Freer and 60 miles west-northwest of the city of Corpus Christi. Our property holdings consist of mineral leases from private landowners covering approximately 2,759 gross and net acres of mineral rights. The nearby Rosita South property (also known as the Cadena area) consists of mineral leases from private land owners on approximately 1,795 gross and 1,479 net acres. All of the leases for the Rosita and Rosita South areas provide for payment of sliding scale royalties that are based upon the price of uranium, ranging from 6.25% to18.25% of uranium sales produced from the leased lands. Under the terms of the leases the lands can be held after the expiration of their primary term and secondary terms, as long as we are carrying out restoration and reclamation activities. The leases have primary and secondary terms ranging from 2012 to 2016, and provisions to extend the leases beyond the initial terms. We hold these leases by payment of annual property rental fees ranging from $10 to $30 per acre.

Accessibility. Access to the Rosita project and process facility is good, from an improved company-owned private drive that connects with an unpaved but maintained county road, which in turn connects with to Texas Farm to Market Road 3196, about one mile northeast of the intersection of State Highway 44 and FM 3196 in Duval County.

Electrical power for the Rosita project is readily available, with an industrial-scale power line extending to the Rosita process plant.

History. Initial production of uranium from the Rosita project, utilizing the in-situ recovery (ISR) process, commenced in 1990, and continued until July 1999. During that time, we produced 2.64 million pounds of U3O8. Production was halted in July of 1999 due to depressed uranium prices, and resumed in June 2008. Technical difficulties, coupled with a sharp decline in uranium prices, led to the decision to suspend production activities in October, 2008, after the production of 10,200 pounds of U3O8. We have had no production from the Rosita project since that time.

Project Geology. Uranium mineralization at the Rosita project occurs as roll-fronts hosted in porous and permeable sandstones of the Goliad Formation, at depths ranging from 125 to 350 feet below the surface.

Restoration and Reclamation. The Rosita project is comprised of four TCEQ authorized production areas. Production areas 1 and 2 are depleted, and groundwater restoration has been completed to regulatory standards. Production areas 3 and 4 contain immaterial uranium reserves that have yet to be produced. Production areas 1 and 2 consist of seven wellfields whose groundwater has been restored by the circulation and processing of approximately 1.3 billion gallons of reverse osmosis treated water. In 2013 we completed the final phase of TCEQ required stabilization in production areas 1 and 2. The Company began plugging wells in production areas 1 and 2 in 2014 and completed those activities in 2016. TCEQ has accepted that plugging was completed in accordance with the approved closure plan. Remaining wells for other uses are being transferred or reclassified in order to complete closure of the two production areas. During 2017, the Company incurred costs relating to surface reclamation and standby of the aforementioned production areas. Surface reclamation is now underway and is expected to continue through the second quarter of 2018.

Permitting Status. A radioactive material license issued by the Texas Commission on Environmental Quality (TCEQ) for the Rosita project is in timely renewal. On August 30, 2012, we filed the requisite application for renewal of our underground injection control permit and it was issued on October 20, 2014. Production could resume in areas already included in existing production area authorizations. As new areas are proposed for production, additional authorizations from the TCEQ under the permit will be required.

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Vasquez Project, Duval County, Texas

The Property. Our Vasquez project is located in southwestern Duval County, Texas, about seven miles north-northwest of the town of Hebbronville and 100 miles southwest of Corpus Christi. The property consists of a mineral lease on 872 gross and net acres. While the primary term of the mineral lease expired in February 2008, we continue to hold the lease by carrying out restoration activities. We pay an annual rental fee to the property owner, and the lease provides for the payment of a sliding-scale production royalty of 6.25% of uranium sales below $25.00 per pound, increasing to 10.25% for uranium sales occurring at or above $40.00 per pound of U₃O₈.

Accessibility. Access to the Vasquez project area is good from a Company-owned and improved private drive to an improved ranch road that connects to Texas State Highway 359, a short distance northwest of Hebbronville.

Adequate electrical power is available in the project area, with a power line extending onto the property to service our facilities at the Vasquez project.

History. We commenced production from the Vasquez project in October 2004, but we have had no production from the project since 2008.

Project Geology. Uranium mineralization at the Vasquez project occurs as roll-fronts within porous and permeable sandstones the Oakville Formation, at depths ranging from 200 to 250 feet below the surface.

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Restoration and Reclamation. We conducted restoration and reclamation activities at the Vasquez project through 2013, and since 2014 the project has been in the required groundwater stabilization period. On October, 8, 2017, We requested acknowledgement that restoration was completed and submitted the results of stability to the TCEQ. On, November 3, 2017, the TCEQ acknowledged completion of restoration. We notified the state of its intent to begin P&A activities for all production areas at the Vasquez site which commenced on December 4, 2017. P&A will continue into 2018 and surface reclamation will begin immediately after that is completed.

The Vasquez project consists of two authorized production areas. Production area 1 consists of five wellfields and production area 2 consists of two wellfields. At the end of 2013, groundwater restoration was completed at all wellfields in all production areas. In 2014, both production areas were placed into stability and remained in this status through November 2017. Groundwater restoration has been completed for the entire project. Since the commencement of groundwater restoration activities at the end of 2007, we have treated approximately 640 million gallons of groundwater at the Vasquez project.

Permitting Status. A radioactive material license issued by the TCEQ is in timely renewal. On July 10, 2012 we filed the requisite application for renewal of our underground injection control permit. On September 23, 2014 the renewal was issued by the TCEQ. Vasquez UIC permit URO3050 was approved for a restoration range table amendment in 2016 and was approved on February 13, 2017.

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Butler Ranch Project, Karnes County, Texas

The Property. We acquired the Butler Ranch project from Rio Grande Resources in 2014, as part of a larger property exchange with them. Our property is comprised of non-contiguous fee leases that cover an area of about 990 acres of mineral rights. We can hold the leases by payment of annual rental fees, ranging from $10 to $25 per acre. Each of the leases makes provision for the payment of royalties of 10% of sales to the property owners. During 2017, all of the Butler Ranch mineral leases were up for renewal. Several landowners opted not to renew, resulting in a drop of acreage from approximately 1,542 acres, to the current 990 acres.

Accessibility. The Butler Ranch project is located in the southwestern end of Karnes County, Texas, about 45 miles southeast of the city of San Antonio, and 12 miles northwest of the town of Kenedy. Numerous paved state and federal highways are present within close proximity of the project area, and maintained farm and oilfield access roads cross all parts of the project.

Numerous electrical lines, many of which are of industrial grade to service oil and gas production facilities, are present throughout the area of the project.

History. The project is situated in the southwestern end of the Karnes County uranium mining district, which was one of the largest uranium production areas in Texas. Numerous open pit mines were developed and operated in the area, including important production operations by Conoco, Susquehanna-Western, Pioneer Nuclear, and Chevron Resources. The historic uranium activities focused upon deposits that were situated above the water table, and the mineralization recovered from the open pit mines was processed in conventional mills owned and operated by Conoco, Susquehanna-Western, Pioneer Nuclear and Chevron Resources.

There has not been any uranium production from the Company’s properties.

Project Geology. Uranium mineralization at Butler Ranch occurs primarily in the form of roll-front deposits hosted primarily in sandstones of the Jackson Group, including the Deweesville and Stones Switch units. Some mineralization in the area occurs as tabular bodies associated with lignite (carbonaceous material) or in somewhat permeable units in the Conquista Clay as well.

Historical mining activities in the project area focused upon deposits that were positioned above the water table, while our targets are situated below the water table and may be suitable for in-situ recovery methods.

Project Activities. In 2015, we acquired a substantial amount of historical exploration drilling information and other geological data for our properties in the Butler Ranch area. Detailed technical studies of this information have been carried out, and this new information is being combined with other data that we hold in order to further evaluate the potential of the Butler Ranch project.

Permitting Status. The Company has not applied for any exploration permits across the Butler Ranch project.

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NEW MEXICO PROJECTS

General

We hold a significant portfolio of properties throughout the extent of the Grants mineral belt of west-central New Mexico (see the above map). Included within our New Mexico property portfolio are fee surface and mineral rights that we own, fee surface and mineral rights leased from third parties, state of New Mexico mining leases, and owned patented and unpatented lode mining claims. Collectively, this property position represents one of the largest mineral rights holdings in the Grants mineral belt.

The Grants mineral belt is an approximately 100-mile-long northwesterly trending belt of sandstone-hosted uranium deposits that historically have been the largest source of uranium production in the United States. During the period of mining activity in the Grants mineral belt, generally between the early 1950s and the mid-1980s, more than 80 underground and open pit mines were developed and operated by several mining companies. At various times during the productive life of the Grants mineral belt, six uranium processing mills were built and operated by the Anaconda Company, Homestake Mining Company, Kerr-McGee, Phillips Petroleum, Sohio Western and United Nuclear.

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Cebolleta Project

General. Our Cebolleta project is located in west-central New Mexico, approximately 45 miles west-northwest of the city of Albuquerque. It is situated in the Laguna mining district, an area that has seen considerable uranium mining activity since the 1950s.

The Property. In March 2007, we entered into a lease with La Merced del Pueblo de Cebolleta (the “Cebolleta Land Grant”), a privately held land grant, to lease the Cebolleta property (the “Cebolleta Lease”), which is composed of approximately 6,717 acres of fee (deeded) surface and mineral rights. The Cebolleta Lease was affirmed by the New Mexico District Court in Cibola County in April 2007. The Cebolleta Lease provides for: (i) a term of ten years and so long thereafter as Cibola is conducting operations on the Cebolleta property; (ii) initial payments to the Cebolleta Land Grant of $5,000,000; (iii) a recoverable reserve payment equal to $1.00 multiplied by the number of pounds of recoverable uranium reserves upon completion of a feasibility study to be completed within six years, less (a) the $5,000,000 referred to in (ii) above, and (b) not more than $1,500,000 in annual advance royalties previously paid pursuant to (iv); (iv) annual advanced royalty payments of $500,000; (v) gross proceeds royalties ranging from 4.50% to 8.00% based on the then current price of uranium; (vi) employment opportunities and job-skills training for the members of the Cebolleta Land Grant and (vii) funding of annual higher education scholarships for the members of the Cebolleta Land Grant. The Cebolleta Lease provides us with the right to explore for, mine, and process uranium deposits present on the Cebolleta project. In February 2012, we entered into an amendment of the Cebolleta Lease (the “Cebolleta Lease Amendment”) amending the Cebolleta Lease, subject to approval of the Thirteenth Judicial District. Pursuant to the Cebolleta Lease Amendment, the date for the completion of the feasibility study was extended from April 2013 to April 2016. In addition, the date has been further extended subject to a reduction in the $6,500,000 initial payment and annual advance royalty payments deductions to the recoverable reserve payment. In the fall of 2017, the Company negotiated a second amendment to the Cebolleta Lease that included a reduction of the advance royalty payment to $350,000 for three years, after which the payments return to the prior formula. Additionally, and for the duration of the agreement, the requirement for a feasibility report has been removed, the reserve payment has been eliminated in favor of a single payment of $4.0 million upon commencement of production and the gross proceeds royalty has been fixed at 5.75%.

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Accessibility. The Cebolleta project is situated in the eastern-most portion of Cibola County, New Mexico. It is located approximately 45 miles west-northwest of the city of Albuquerque, and about 10 miles north of the town of Laguna. A major transcontinental highway (US Interstate Highway I-40) traverses the region about 12 miles south of the project and a well-maintained state of New Mexico paved highway, New Mexico State Highway 279 connects I-40 at the village of Laguna with the settlement of Seboyeta, which is located approximately four miles northwest of the project. An all-weather graded gravel road and several private roads of varying quality cross the project lands and provide access to nearly all parts of the project area. During periods of precipitation access to the immediate project area on the unmaintained private roads may be hindered due to muddy ground conditions, but these events are normally of short duration.

One power line is present at the north end of the project area, and a major high voltage electrical transmission line and sub-station are present approximately five miles northeast of the main part of the Cebolleta project area.

History. Parts of the Cebolleta project were developed as open pit and underground mines, and uranium was produced from the project area during the 1960s, through the early 1980s. Initial production was attained from a small underground mine in the St. Anthony area developed by Climax Uranium in the 1950s. The project was revitalized in the mid-1960s after various leases were acquired by United Nuclear, who also conducted an extensive exploration program on the property, and subsequently developed two open pit and one underground mine on the southern part of the project area. United Nuclear ceased uranium production from their holdings in the project area in 1979.

Sohio Western Mining and Reserve Oil and Minerals carried out an extensive exploration drilling program on lands that comprise the northern part of the current Cebolleta project area, and subsequently discovered five discrete uranium deposits. Sohio developed one underground mine, and constructed a uranium processing mill on a nearby parcel of land in the early to mid-1970s. Sohio operated the mine and mill complex until it was shut down in 1981. There has been no uranium production from the property since 1981.

Project Geology. The Cebolleta project is the site for six sandstone-hosted uranium deposits that occur as discrete flat-lying tabular bodies of uranium mineralization that are hosted within the Jackpile sandstone unit of the Jurassic-age Morrison Formation. The mineralized bodies are contained within channels in the Jackpile sandstone, and are found at depths ranging from approximately 250 to 850 feet below the surface. The deposits are situated above the local and regional water tables.

Project Activities. The Company completed a Technical Report for the Cebolleta project in April 2014. Based on the quantity and quality of the mineral resource, the Technical Report recommends the advancement of the Cebolleta project to a Preliminary Economic Assessment or scoping level study. The Cebolleta Technical Report recommended proceeding with the next step of “confirmation drilling” with the objective of raising the confidence levels of a significant portion of the mineral resources. Another recommendation in the Technical Report was to drill and develop an initial resource model and mineral resource estimate for the historic St. Anthony mine area. We are not contemplating any current work at Cebolleta.

Permitting Status. The Company does not hold any current exploration or mining permits for the Cebolleta project at this time. A previously held exploration permit for the project was closed out with the State of New Mexico in 2017.

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Juan Tafoya Project

General. Our Juan Tafoya project is located in west-central New Mexico, near the eastern end of the Grants mineral belt. It is situated approximately 45 miles west-northwest of the city of Albuquerque, and 25 miles northeast of the town of Laguna.

Exploration programs carried out by Bokum Resources, DeVilliers Nuclear, Exxon, and Kerr-McGee during the late 1960s and 1970s discovered a group of sandstone-hosted uranium deposits that were determined to be southeasterly extensions of the Grants mineral belt. Ownership consolidation efforts resulted in the various properties and deposits falling under the control of Bokum and Kerr-McGee. Bokum, and their project partner Long Island Lighting Company undertook a development program on the Juan Tafoya project that resulted in the construction of a uranium mill and the partial development of shafts to access the largest uranium deposit on the Juan Tafoya project. Development of the Juan Tafoya project was halted because of the bankruptcies of the partners, and the project was ultimately abandoned and a portion of the surface facilities (mine infrastructure) and mill were dismantled. There has not been any uranium production from deposits on the Juan Tafoya project lands.

The project has an industrial grade power line and there are three water wells present on the property. A 14-foot diameter concrete-lined shaft is present at the larger of the two uranium deposits, and a 6-foot diameter steel cased “ventilation” shaft is in place.

The Property. The Juan Tafoya project is comprised of lands covering an area of approximately of 4,097 acres of fee (deeded) surface and mineral rights that are owned by the Juan Tafoya Land Corporation (“JTLC”) and 24 leases with private owners of small tracts covering a combined area of approximately 115 acres. The JTLC lease (the “JT Lease”) has a term of ten years, and it can be extended on a year-to-year basis thereafter, so long as we are conducting operations on the Juan Tafoya project. Additionally, the JT Lease required: (i) an initial payment to JTLC of $1,250,000; (ii) annual rental payments of $225,000 for the first five years of the lease and $337,500 for the second five years; (iii) after the second five years, annual base rent of $75 per acre; (iv) a gross proceeds royalty of 4.65% to 6.5% based on the prevailing price of uranium; (v) employment opportunities and job-skills training programs for shareholders of the JTLC or their heirs, (vi) periodic contributions to a community projects fund if mineral production commences from the Juan Tafoya project and (vii) funding of a scholarship program for the shareholders of the JTLC or their heirs. We are obligated to make the first ten years’ annual rental payments notwithstanding the right to terminate the JT Lease at any time, unless (a) the market value of uranium drops below $25 per pound, (b) a government authority bans uranium mining on the Juan Tafoya project, or (c) the project is deemed uneconomical by an independent engineering firm. The Company’s most recent negotiations with JTLC, completed in the fall of 2017, allow for a reduction of advance royalty payments to $174,000 per annum for three years, after which they return to the original formula. Additionally, the gross proceeds royalty rate is fixed at 4% for the remainder of the agreement.

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The fee mineral leases covering the individually-owned small tracts have similar royalty provisions as the JTLC lease and have annual rental obligations of $9,526.

The JT Lease and the “small tract” fee mineral leases provide us with the right to explore for, mine and process uranium deposits present on the leased premises.

In January 2007, we entered into a letter agreement with International Nuclear, Inc. to acquire certain technical data relating to the Juan Tafoya project. Pursuant to the letter agreement, a cash payment was made and a royalty was assigned to International Nuclear, Inc. of $0.25 per pound of uranium recovered from the Juan Tafoya project by the Company with a maximum payout of $1,000,000.

Accessibility. The Juan Tafoya project is located in west-central New Mexico, about 25 miles north of the town of Laguna. Access to the project area from Albuquerque is over a four lane Interstate highway (US I-40) to the town of Laguna (a distance of approximately 45 miles) and a paved two-lane highway (for a distance of 15 miles) to the village of Seboyeta and a further 16 miles over a well-maintained all-weather gravel road. Several private roads of varying quality cross the project lands and provide access to nearly all parts of the project area. Vehicle access to most parts of the Juan Tafoya project area is good, except for short periods following rain or snow storms.

History. The Juan Tafoya project has been of considerable interest to the U.S. uranium industry since the late 1960s to early 1970s. Exploration and pre-development activities were carried out on and adjacent to the Juan Tafoya project by several companies, including Bokum Resources, DeVilliers Nuclear, Exxon, Kerr-McGee and Nuclear Dynamics, but no mining operations were ever undertaken on the Juan Tafoya project.

The Juan Tafoya project was nearly fully developed for uranium mining and processing, with the construction of a mill and related mine infrastructure. However, all plant and equipment have been removed from the Juan Tafoya project and the project has no significant plant or equipment, including subsurface improvements and equipment. However, there is a 12-foot diameter concrete lined shaft (to a depth of about 1,850 feet) and a five-foot diameter steel lined ventilation shaft (to a depth of about 2,200 feet) at the northwestern end of the Marquez deposit.

Project Geology. The uranium mineralization in the Juan Tafoya project is hosted within sandstones of the Westwater Canyon Member, which comprises approximately the lower half of the Morrison Formation. Mineralization in the Marquez deposit, which is the larger of the two defined deposits, occurs as a series of elongate lenses that get progressively deeper to the east. These lenses appear to have shapes that are reminiscent of “trend-type” deposits elsewhere in the Grants mineral belt and are thought not to be amenable to ISR methods. The mineralized zones at the Juan Tafoya project are below the water table, at depths of approximately 2,100 feet from the surface.

Project Activities. A Technical Report was completed for the Juan Tafoya project in June 2014. The Technical Report concluded that the Juan Tafoya project was ready for the next stage of in-fill confirmation drilling to upgrade the mineral resources. The Technical Report recommended follow-up work in two phases:

● Phase 1. Conduct a confirmation drilling program of approximately 35,000 feet in 16 holes; and

● Phase 2. Prepare a Preliminary Economic Assessment including hydrogeological work, geotechnical analysis, conceptual mining methods study, and capital and operating costs, based upon the results of the Phase 1 work program.

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We are not contemplating any near-term work at the Juan Tafoya project.

Water Rights. Under the terms of the JTLC lease the Company has the right to utilize approximately 1,800 acre feet of water rights that are owned by the JTLC.

Permits. We have completed numerous meteorological, archaeological, biological, and radiological surveys of the Juan Tafoya project, in order to support applications for drilling permits. We hold a Sub-part 4 Regular Exploration Permit, MK023ER-R3, issued by the New Mexico Energy, Minerals and Natural Resources Department that allows us to conduct exploration drilling at the Juan Tafoya project.

OTHER

New Mexico Properties

We hold approximately 34,000 acres of other immaterial properties in New Mexico including the Ambrosia Lake, Nose Rock and West Largo projects. We do not currently have any plans to explore these projects in the near-term.

Azarga Uranium Corp. Transaction, Custer and Fall River Counties, South Dakota

We hold a 30% net proceeds interest from future uranium production from certain unpatented lode mining claims, fee leases and state leases currently controlled by Azarga Uranium Corp. (formerly Powertech Uranium) (“Azarga”) in the Dewey-Burdock area, Custer and Fall River Counties, South Dakota. Prior to our acquisition of Neutron Energy Inc. (“Neutron”), Neutron transferred its property interests in the Dewey-Burdock area to Azarga for which Neutron received (i) a 30% net proceeds interest of future uranium production and sales from Neutron’s former lands in the Dewey-Burdock area, (ii) 327 acres of mining claims and state leases along with associated historical drilling data for properties situated near Edgemont, South Dakota, (iii) 4,117 acres of mining claims in the Ambrosia Lake mining district in New Mexico and (iv) 1,709 acres of mining claims and leases in the Shirley Basin area of Wyoming. Azarga has filed permit applications with the NRC and USEPA and submitted a Plan of Operation to the BLM for its Dewey-Burdock uranium ISR project.

Our former acreage in the Dewey-Burdock area that is subject to the 30% net proceeds interest payable to us consists of approximately 1,620 acres of unpatented lode mining claims and private leases within Azarga’s proposed Dewey-Burdock permit area and an additional 4,667 acres of prospective claims and leases elsewhere within their project permit area.

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WORK COMPLETED ON PROPERTIES IN 2017

	Statement of Operations (1)						Balance Sheet
Property	Operating Expenses		Mineral Property Expenses		Impairment		Property, Plant & Equipment		Restoration Liability (2)		Total Expenditures
	(expressed in thousands of dollars)
Columbus Basin project	$	-	$	866	$	-	$	-	$	-	$	866
Railroad Valley project		-		238		-		-		-		238
Sal Rica project		-		93		-		-		-		93
Temrezli project		196		66		-		-		-		262
Rosita project		535		55		-		-		39		629
Kingsville Dome project		647		163		140				-		950
Vasquez project		524		97		-		-		58		679
Butler Ranch project		-		21		-		-		-		21
Cebolleta project		-		538		11,296		-		-		11,834
Juan Tafoya project		-		528		-		-		-		528
Other		-		17		-		-		-		17
	$	1,902	$	2,682	$	11,436	$	-	$	97	$	16,117

(1)	See Item 7—Management Discussion and Analysis below for discussion of 2017 mineral property expense charged to the Statement of Operations.
(2)	For description of 2017 reclamation activities at the Rosita and Vasquez projects, see discussion at Item 2—Properties above.

INFRASTRUCTURE

The Company’s carrying value of property, plant and equipment at December 31, 2017 by location is as follows:

	Net Property, Plant and Equipment at December 31, 2017
(thousands of dollars)	Turkey		Texas		New Mexico		Corporate		Net book value
Uranium plant	$	-	$	8,304	$	-	$	-	$	8,304
Mineral rights and properties-Uranium		17,968		-		7,806		-		25,774
Other property, plant and equipment		11		1,109		-		211		1,331
Total net book value	$	17,979	$	9,413	$	7,806	$	211	$	35,409

As noted in the table above, the Company’s most significant uranium property infrastructure is located in South Texas. The Company’s two licensed processing facilities are located at the Kingsville Dome project and at the Rosita project. The Kingsville Dome facility is currently capable of processing 800,000 pounds of U₃O₈ annually, expandable to 1.6 million pounds. The Kingsville Dome plant has a carrying value of $1.8 million. The Rosita facility is also currently capable of processing 800,000 pounds of U₃O₈ annually, and is also expandable to 1.6 million pounds. The Rosita plant is a newer facility and has a carrying value of $4.0 million. Each of these plants has been idle since 2009 and each will require approximately $0.8-$1.0 million of capital expenditures to return them to current productive capacity. The Company also has portable satellite ion exchange equipment at the Kingsville Dome project and the Rosita project with carrying values at December 31, 2017 of $1.7 million and $0.8 million, respectively. We are considering the relocation of our Rosita uranium processing plant to the Temrezli project in Turkey at such time as we begin developing Temrezli.

INSURANCE

Our properties are covered by various types of insurance including property and casualty, liability and umbrella coverage. We have not experienced any material uninsured or under insured losses related to our properties in the past and believe that sufficient insurance coverage is in place.

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ITEM 3. LEGAL PROCEEDINGS

DISPUTE OVER KLEBERG SETTLEMENT AGREEMENT

On September 28, 2007, the Company’s Texas base subsidiary, URI, Inc. (“URI”), filed suit against Kleberg County in the 105^th Judicial District Court, Kleberg County, Texas for declaratory relief interpreting the December 2004 Settlement Agreement between Kleberg County (the “County”) and URI as to the level of groundwater restoration URI agreed to achieve in Kingsville Dome production areas 1 and 2 and for recovery of URI’s legal fees and costs of the suit. The County filed a counterclaim alleging URI had breached the terms of the December 2004 Settlement Agreement, asked for a Declaratory Judgment and injunctive relief ordering URI to cure various alleged breaches of that agreement and asked that the County be awarded its legal fees and costs of the suit. On December 13, 2012, the Court ruled that URI is permitted to continue ISR operations in the Kingsville Dome project but must continue to restore Well I-11A to its previous use. The Court also ruled that URI breached the December 2004 Settlement Agreement when it tried to rely on 1987 data (in addition to original 1985 data) drawn from Well I-11 to establish clean-up standards applicable under the December 2004 Settlement Agreement for the well, and the Court awarded nominal damages in the amount of $20.00. On November 13, 2013, the Court ruled on attorney’s fees and found that neither URI nor the County was entitled to attorney’s fees.

On February 10, 2014, the County filed a notice of appeal on the merits judgment of December 13, 2012 and the attorney’s fee judgment on November 13, 2013. On February 12, 2014, URI cross-appealed on both the merits judgment and the attorney’s fees judgment. Following the submission of opening briefs, response briefs and reply briefs in the fall of 2014, on January 15, 2016 an oral hearing on the matter was held before the 13^th Court of Appeals in Corpus Christi, Texas. On January 28, 2016, the 13^th Court of Appeals issued a memorandum opinion that found in favor of Kleberg County on four issues: use of 1985 data as opposed to 1987 data to establish the clean-up standards for Well I-11 (upholding the trial court decision); an award of attorney fees to Kleberg County as a result of prevailing on that issue (reversing the trial court decision); requiring specific performance by URI to restore Well I-11 prior to mining in production area 3 (reversing the trial court decision); and requiring URI to restore production areas 1 and 2 using groundwater at a rate of 240 million gallons a year (reversing the trial court decision). In addition, the Court of Appeals opinion held in favor of URI on two issues: the applicability of and notice made by URI to invoke the force majeure provisions in the Settlement Agreement as regards groundwater restoration activities (upholding the trial court decision); and that URI provided Kleberg County with proper notice and substantial performance in accordance with the Settlement Agreement (upholding the trial court decision).

On March 14, 2016, URI filed a motion for rehearing and reconsideration en banc before the 13^th Court of Appeals of Texas. URI argued that the Court should grant rehearing or reconsideration because its prior opinion, which added new terms to the 2004 Settlement Agreement, ignored established precedent and improperly violated the prohibition against consideration of extraneous matters when interpreting unambiguous contracts. On March 30, 2016, the 13^th Court of Appeals denied the motion for rehearing en banc. On June 15, 2016, URI filed a petition for review with the Texas Supreme Court raising the issue of whether a court may alter the explicit terms of an unambiguous contract based on one party’s subjective belief regarding whether certain data meets the requirements of the contract as well as other related issues. On August 19, 2016, the Supreme Court requested Kleberg County to file a response, and on October 19, 2016, Kleberg County filed a response to the petition for review. On December 5, 2016, URI filed its reply pleading that addressed the arguments made by Kleberg County in its response pleading. On January 20, 2017, the Texas Supreme Court informed the parties that it would accept further briefing on the merits and set a briefing schedule that ran through March 28, 2017. Following the submittal of all the briefs by both parties, on June 23, 2017, the Texas Supreme Court granted the Petition for Review. On October 12, 2017 the Texas Supreme Court held an oral argument. URI has no indication as to when or how the Texas Supreme Court will rule on the matter.

OTHER

The Company is subject to periodic inspection by certain regulatory agencies for the purpose of determining compliance by the Company with the conditions of its licenses. In the ordinary course of business, minor violations may occur; however, these are not expected to result in material expenditures or have any other material adverse effect on the Company.

ITEM 4. MINE SAFETY DISCLOSURES

Not Applicable.

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PART II

ITEM 5. MARKET FOR REGISTRANT’S COMMON EQUITY, RELATED STOCKHOLDER MATTERS AND ISSUER PURCHASES OF EQUITY SECURITIES

STOCK PRICE INFORMATION

WWR’s common stock is traded on the NASDAQ Capital Market.

The following table sets forth the intraday high and low sales prices for our common stock as reported on the NASDAQ Capital Market for the periods indicated:

	Common Stock
Fiscal Quarter Ending	High		Low
December 31, 2017	$	1.42	$	.76
September 30, 2017		1.70		1.25
June 30, 2017		2.18		1.30
March 31, 2017		4.00		1.35
December 31, 2016		1.67		1.06
September 30, 2016		1.83		1.27
June 30, 2016		2.49		1.45
March 31, 2016		6.84		2.42

As of March 1, 2018, there were 406 holders of record of WWR’s common stock.

DIVIDENDS

We have never paid any cash or other dividends on our common stock, and we do not anticipate paying dividends for the foreseeable future. We expect to retain our earnings, if any, for the growth and development of our business. Any future determination to declare dividends will be made at the discretion of our Board of Directors and will depend on our financial condition, results of operations, capital requirements, general business conditions and other factors that our Board of Directors may consider relevant.

ITEM 6. SELECTED FINANCIAL DATA

Smaller reporting companies are not required to provide the information required by this item.

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 consolidated financial statements as of and for the two years ended December 31, 2017, and the related notes thereto appearing elsewhere in this Annual Report on Form 10-K, which have been prepared in accordance with generally accepted accounting principles in the United States (“U.S. GAAP”). This discussion and analysis contains forward-looking statements that involve risks, uncertainties and assumptions. 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” above and elsewhere in this Annual Report on Form 10-K. See “Cautionary Note Regarding Forward-Looking Statements” above.

INTRODUCTION

WWR is an energy minerals exploration and development company. We are focused on expanding our energy minerals strategy, which includes developing our lithium business while maintaining optionality on the future rising uranium price with our significant uranium property holdings in the Republic of Turkey, Texas and New Mexico. Incorporated in 1977, WWR also owns an extensive information database of historic drill-hole logs, assay certificates, maps and technical reports for uranium properties located in the western United States.

We established our lithium business in 2016 and currently control mineral rights encompassing approximately 36,730 acres across three prospective lithium brine basins in Nevada and Utah. We are conducting exploration and geological evaluation of these properties in 2017 and 2018 for potential development of any lithium resources that may be discovered there.

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The focus of our uranium business continues to be on advancing the Temrezli in-situ recovery (“ISR”) uranium project in central Turkey when uranium prices permit economic development of this project. We control extensive exploration properties in Turkey under eight exploration and operating licenses covering approximately 39,000 acres. In Texas, we have two licensed and currently idled uranium processing facilities and approximately 11,000 acres of prospective ISR uranium projects. In New Mexico, the Company controls mineral rights encompassing approximately 188,700 acres in the prolific Grants Mineral Belt, which is one of the largest concentrations of sandstone-hosted uranium deposits in the world.

RECENT DEVELOPMENTS

Agreement to Acquire Alabama Graphite

On December 13, 2017, the Company entered into an arrangement agreement to acquire all of the outstanding common shares of Alabama Graphite Corp. (“Alabama Graphite”) in an all-stock acquisition. Upon completion of the acquisition, former Alabama Graphite shareholders would own approximately 29.4% of the outstanding shares of the combined company based on the number of WWR and Alabama Graphite common shares outstanding as of February 26, 2018. The Westwater Board of Directors expects the acquisition to provide significant strategic and financial benefits to the Company’s stockholders, including participation in the value chain of critical minerals for the high growth battery market, operational efficiencies and improved access to capital. Closing of the acquisition remains subject to various conditions, including approval by AGC’s and the Company’s respective stockholders and approval by the Supreme Court of British Columbia.

Lithium Business Expansion

On June 20, 2017, the Company acquired its third lithium exploration project, through the staking of 9,270 acres of federal placer mining claims within the Railroad Valley of central Nevada. The Railroad Valley Project is located approximately 75 miles west of Ely, Nevada.

Columbus Basin Data Review and Exploration Drilling

On April 5, 2017, the Company announced that its independent geophysical consultant has completed the review, integration and reinterpretation of historical geophysical survey data acquired by the Company and covering its Columbus Basin lithium brine exploration project in Nevada. Among other things, the results of the work indicated that the depth of the Columbus Salt Marsh basin is greater than previously anticipated and identified certain targets for lithium brine exploration. In July 2017, the Company began a Phase-1 exploration drilling program at the Columbus Basin project.

On October 31, 2017, the Company announced that it has completed the Phase 1 exploration project at this project and reported the following results:

● Three core holes were completed for a total of 3,870 ft. of drilling.

○	The maximum drilled depth was 1,680 ft.
○	Fluids with high total dissolved solids (TDS) were identified in all three holes.

● In-house laboratory work performed at its Kingsville, Texas facility returned lithium concentrations of up to 43 parts per million (ppm) and boron concentrations of up to 173 ppm.

Planning is underway for a Phase 2 exploration program at the Project. As part of the Phase 2 program, Westwater has filed a Notice of Intent to drill in the Nina claim block and is evaluating the Phase 1 results and the results of drilling by Caeneus Minerals Ltd. on nearby lithium properties.

Sal Rica Exploration Planning

A brine sampling program at the Sal Rica Project was designed and implemented to infill previous shallow aquifer sampling completed by Mesa Exploration Corp. in 2016. The resultant combination of the new Westwater data and the existing Mesa Exploration Corp. data now provide shallow aquifer lithium concentration data on variable 1 to 2 mile centers, depending on site accessibility, across the entirety of the 13,260 acre project area.

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In addition to the recent groundwater sampling event, Westwater has also completed new geophysical interpretations of the Sal Rica project area. This data is being integrated into a conceptual model of the exploration target, and will guide the ongoing planning of a drilling and hydrogeologic characterization program to further expand and define the shallow, lithium bearing, brine aquifer. So far this work has outlined a strong lithium brine anomaly that covers an area of over twenty (20) square miles, with lithium values up to 100 ppm, all at shallow depths.

Westwater has commenced the permitting process with the U.S. Bureau of Land Management (“BLM”), and the State of Utah, to field an exploration program that optimizes project access and limits environmental disturbance, minimizes cost, and maximizes overall data quality.

Option Agreement for Lithium Brine Claims

On March 24, 2017, the Company’s wholly owned subsidiary Lithium Holdings Nevada LLC entered into an option agreement to purchase a block of unpatented placer mining claims covering an area of approximately 3,000 acres within the Columbus Salt Marsh area of Esmeralda County, Nevada. The claims adjoin a portion of the Company’s current property holdings at its Columbus Basin project, expanding the project area within the basin to approximately 14,200 acres. The Company has the right to conduct exploration activities on the claims during the one-year option period. Under the option agreement, the Company may acquire the mineral property claims on or before March 24, 2018 in exchange for 200,000 shares of WWR common stock and a 1% net smelter return royalty on the claims.

Equity Financings

Confidentially Marketed Public Offering

On January 19, 2017, the Company completed a registered public offering for net proceeds of $8.9 million. The Company sold 1,399,140 shares of common stock at a price of $2.01 per share and 3,426,731 pre-funded warrants at a price of $2.00 per warrant. The warrants had an exercise price of $0.01. All of the pre-funded warrants have been exercised.

Registered Direct Offering

On February 16, 2017, the Company completed a registered direct offering for net proceeds of $4.5 million with Aspire Capital whereby Aspire Capital purchased 2,100,000 shares of common stock at a price of $1.58 and 748,101 pre-funded common stock purchase warrants at a price of $1.57. The warrants had an exercise price of $0.01 per share and a term of three years. All of the pre-funded warrants have been exercised.

Controlled Equity Offering Sales Agreement with Cantor Fitzgerald (“Cantor”)

On April 14, 2017, the Company entered into an at-the-market offer (the “ATM Offering”) with Cantor acting as sales agent. Under the ATM Offering, the Company may from time to time sell shares of its common stock having an aggregate offering amount up to $30.0 million in “at-the-market” offerings, which shares are registered under a registration statement on Form S-3, which was declared effective on March 9, 2017. The Company pays Cantor a commission equal to 2.5% of the gross proceeds from the sale of any shares pursuant to the ATM Offering. As of March 1, 2018, the Company had sold 812,723 shares of common stock for net proceeds of $1.2 million under the ATM Offering. As a result, the Company had approximately $28.8 million remaining available for future sales under the ATM Offering. The Company’s previous ATM Offering with BTIG LLC was fully utilized as of December 31, 2016.

Common Stock Purchase Agreement (“CSPA”) with Aspire Capital

On September 25, 2017, the Company entered into the CSPA with Aspire Capital to place up to $22.0 million in the aggregate of the Company’s common stock on an ongoing basis when required by the Company over a term of 30 months. The Company will control the timing and amount of sales to Aspire Capital, and at a price based on market prices at that time. As consideration for Aspire Capital entering into the purchase agreement, the Company issued 880,000 shares of its common stock to Aspire Capital. The shares of common stock subject to the CSPA were registered pursuant to the Company’s effective shelf registration statement on Form S-3. The parties terminated the April 8, 2016 CSPA with Aspire Capital upon entering into the September 25, 2017 CSPA.

On September 27, 2017, pursuant to the CSPA and after satisfaction of certain commencement conditions, Aspire Capital made an initial purchase of 1,428,571 shares of common stock for which the Company received net proceeds of $2.0 million. Additionally, on December 14, 2017, Aspire Capital purchased 150,000 shares of common stock for which the Company received net proceeds of $0.2 million. There were no other sales of common stock pursuant to the CSPA and as of March 1, 2018, $19.8 million of the aggregate $22.0 million remained available for future sales under the CSPA.

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Laramide Asset Sale

On January 5, 2017, Laramide Resources Ltd. (“Laramide”) and the Company closed the sale of the Company’s wholly-owned subsidiary Hydro Resources, Inc., which held the Churchrock and Crownpoint projects, pursuant to a Share Purchase Agreement (the “Laramide SPA”). Under the terms of the Laramide SPA, as amended on December 5, 2016, the Company received the following consideration:

● $2.5 million in cash, of which $250,000 was paid in advance on October 21, 2016;

● $500,000 of Laramide common stock and warrants; and

● a $5.0 million promissory note, secured by a mortgage over the Churchrock and Crownpoint projects. The note has a three-year term and carries an initial interest rate of 5% which then increases to 10% upon Laramide’s decision regarding commercial production at the Churchrock project. Principal payments of approximately $1.5 million are due and payable on January 5 in each of 2018, 2019 and $2.0 million on January 5, 2020. Interest is payable on a quarterly basis, provided however that no interest will be payable prior to the first principal payment in 2018. Laramide will have the right to satisfy up to half of each of these payments by delivering shares of its common stock to the Company, which shares will be valued by reference to the VWAP for Laramide’s common stock for the 20 trading days before the respective anniversary of January 5, on which each payment is due.

Laramide made the first required principal payment on the promissory note in January 2018, consisting of $750,000 in cash and the issuance of 1,982,483 of Laramide’s common shares.

RCF Loan Retirement

On February 9, 2017, the Company repaid $5.5 million of principal plus accrued unpaid interest in cash to retire all of the obligations remaining under that certain loan agreement dated November 13, 2013 by and among the Company, certain of its subsidiaries and Resource Capital Fund V L.P. (“RCF”). In addition, on July 31, 2017, the Company and RCF terminated the Stockholders’ Agreement dated March 1, 2012, pursuant to which RCF had certain participation and Board rights.

RESULTS OF OPERATIONS

Summary

Our consolidated net loss for the years ended December 31, 2017 and 2016 was $19.3 million and $19.6 million or $0.78 and $3.73 per share, respectively. The principal components of these year-over-year changes are as follows:

	For the year ended December 31,
	2017			2016
	(thousands of dollars)
Mineral property expenses	$	(4,584	)	$	(3,248	)
General and administrative		(6,614	)		(7,650	)
Acquisition related costs		(1,003	)		-
Impairment of uranium properties		(11,436	)		(1,673	)
Other operating expenses		(1,181	)		(727	)
Non-operating income/(expenses)		5,530			(6,307	)
Total	$	(19,288	)	$	(19,605	)

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Mineral property expenses

Mineral property expenses for the year ended December 31, 2017 were $4.6 million, as compared with $3.2 million for the year ended December 31, 2016.

The following table details our mineral property expenses for the years ended December 31, 2017 and 2016.

	For the years ended December 31,
	2017		2016
	(thousands of dollars)
Restoration/Recovery expenses
Kingsville Dome project	$	-	$	-
Rosita project		208		9
Vasquez project		113		-
Total restoration/recovery expenses		321		9
Standby care and maintenance expenses
Kingsville Dome project		647		612
Rosita project		327		298
Vasquez project		411		365
Temrezli project		196		498
Total standby care and maintenance expenses		1,581		1,773
Exploration and evaluation costs		812		486
Land maintenance and holding costs		1,870		980
Total mineral property expenses	$	4,584	$	3,248

For the year ended December 31, 2017, mineral property expenses increased by $1.3 million as compared with the corresponding period in 2016. This increase was due to increases in land maintenance and holding costs of $0.9 million, exploration and evaluation costs of $0.3 million, standby care and maintenance costs of $0.1 million and restoration and recovery expenses of $0.3 million. These increases were partially offset by decreases in costs at Temrezli of $0.3 million. These changes were the result of the following:

● an increase of $0.9 million for land maintenance and holding costs related to deferral of the 2016 Juan Tafoya lease payment to 2017 due to lease negotiations and payment of BLM claim fees on the Railroad Valley lithium mineral property which was acquired in 2017;

● an increase of $0.3 million for increased exploration related to lithium projects in Utah and New Mexico;

● an increase of $0.1 million for increased standby care and maintenance costs for the Kingsville Dome, Rosita and Vasquez projects in south Texas;

● an increase of $0.3 million for increased restoration and recovery expenses for Rosita and Vasquez projects in south Texas; and

● A decrease of $0.3 million for decreased permitting and license costs for the Temrezli project in Turkey.

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General and administrative expenses

Significant expenditures for general and administrative expenses for the years ended December 31, 2017 and 2016 were:

	For the year ended December 31,
	2017		2016
	(thousands of dollars)
Stock compensation expense	$	101	$	195
Salaries and payroll burden		2,480		3,055
Legal, accounting, public company expenses		2,816		3,129
Insurance and bank fees		524		525
Consulting and professional services		75		104
Office expenses		495		541
Other expenses		123		101
Total	$	6,614	$	7,650

General and administrative expenses decreased by approximately $1.0 million as compared with the corresponding period in 2016. This decrease was mostly due to the following:

● a decrease in the Company’s salaries and payroll burden of $0.6 million, which was primarily the result of a lower head count in 2017 versus 2016;

● a decrease in legal, accounting, public company expenses of $0.3 million, which was primarily due to lower public company costs in 2017 because of one less shareholders’ meeting and one less director during the year; and

● a decrease in stock-based compensation expense of $0.1 million as there were fewer awards outstanding during most of 2017.

Acquisition related expenses

During 2017, we incurred acquisition related legal and accounting costs of $1.0 million associated with the Alabama Graphite Corp. acquisition. We also advanced $0.8 million to Alabama Graphite pursuant to the Arrangement Agreement and Loan Agreement as of December 31, 2017.

Impairment of uranium properties

During 2017 and 2016, we recorded impairments of $11.4 million and $1.7 million, respectively, to reduce the carrying value of certain uranium properties. Due to continued declining uranium prices in 2017, substantially all of the 2017 impairment charges related to the Company’s Cebolleta/Juan Tafoya project as the carrying value exceeded the project’s cash flows on an undiscounted and discounted basis. The net carrying value of the Cebolleta/Juan Tafoya project after impairment was $7.8 million at December 31, 2017. The 2016 impairment charges consisted of $0.9 million relating to the termination of the Sejita Dome, Nell and Jack Pump projects, $0.2 million relating to physical deterioration at the Kingsville Dome project, and $0.6 million relating to the determination that the Company’s investment in the Butler Ranch project was not recoverable.

Non-operating income and expenses

Disposal of Hydro Resources, Inc.

On January 5, 2017, Laramide and the Company closed the sale of the Company’s wholly-owned subsidiary HRI, which holds the Churchrock and Crownpoint projects, pursuant to a Share Purchase Agreement (the “Laramide SPA”). Under the terms of the Laramide SPA, executed on April 7, 2016 and amended on December 5, 2016, the Company received the following consideration:

● $2.5 million in cash, of which $0.25 million was paid on October 21, 2016;

● 2,218,333 shares of Laramide common stock and 2,218,333 Laramide common stock purchase warrants. Each common stock purchase warrant entitles the Company to purchase one share of common stock of Laramide at a price of CDN$0.45 for a period of 60 months from the date of closing;

63

● a $5.0 million promissory note, secured by a mortgage over the projects. The note has a three-year term and carries an initial interest rate of 5% which then increases to 10% upon Laramide’s decision regarding commercial production at the Churchrock project. Principal payments of approximately $1.5 million are due and payable on January 5 in each of 2018 and 2019, with the balance of $2.0 million due and payable on January 5, 2020. Interest is payable on a quarterly basis, provided however that no interest will be payable until March 31, 2018. Laramide will have the right to satisfy up to half of each of these principal payments by delivering shares of its common stock to the Company, which shares will be valued by reference to the volume weighted average price (“VWAP”) for Laramide’s common stock for the 20 trading days before the respective anniversary of January 5, on which each payment is due;

● a retained 4.0% Net Smelter Return Royalty (“NSR Royalty”) on the Churchrock project; and

● an option to purchase Laramide’s La Sal project and La Jara Mesa projects which expired on January 5, 2018.

The divestiture of HRI was accounted for as an asset disposal and the non-cash consideration received from Laramide was recorded at fair value. The fair value of the shares of Laramide common stock received was determined using the closing share price of Laramide’s stock on January 5, 2017. The fair value of the common stock purchase warrants was determined using the Black-Scholes method on April 27, 2017, which was the date that Laramide’s stockholders approved the issuance of the warrants. The fair value of the notes receivable was determined using the present value of the future cash receipts discounted at a market rate of 9.5%. The Company did not record a separate fair value for the options as the exercise of the options would reduce the amount outstanding under the notes receivable. Due to the high degree of uncertainties surrounding future mine development and minerals prices, as well as limited marketability, the Company determined the fair value of the NSR Royalty to be nil. The following gain was included in our Statement of Operations and was determined using the fair value amounts of the purchase consideration less the carrying value of the Churchrock project:

(thousands of dollars)
Total consideration received	$	6,525
Carrying value of Churchrock project		(2,123	)
Carrying value of other plant and equipment		(31	)
Accounts payable		1
Asset retirement obligation		105
Royalty payable on Churchrock project		450
Gain on disposal of HRI	$	4,927

Interest Income/(Expense)

Interest income of $0.6 million for the year ended December 31, 2017 consisted of accrued interest receivable of $0.2 on the Laramide Note and amortization of $0.5 million on the discount on the Laramide Note. These amounts were partially offset by interest expense of $0.1 million for the amortization of the debt discount and establishment fee. Interest expense of $2.6 million for the year ended December 31, 2016 consisted of interest of $0.7 million payable to RCF, amortization of the debt discount of $1.8 million and amortization of the establishment fee of $0.1 million.

Loss on extinguishment of convertible debt

On December 5, 2016 the Company entered into the Esousa MEA with Esousa whereby Esousa purchased $2.5 million of the Company’s convertible debt and exchanged such debt into shares of common stock of the Company. As a result, the exchange of shares was considered an inducement under accounting rules and the Company recorded a loss of $3.3 million which was the difference between the fair value of shares exchanged and the fair value of the shares issuable pursuant to the terms of the RCF Loan.

Commitment Fees

Commitment fees expense of $0.3 million for the twelve months ended December 31, 2016 was the result of the Company’s issuance of 75,000 shares of common stock to Aspire Capital on February 4, 2016 as consideration for Aspire Capital entering into the Option Agreement. The shares had a fair value of $4.44 per share.

64

FINANCIAL POSITION

Operating Activities

Net cash used in operating activities was $11.6 million for the year ended December 31, 2017, as compared with $12.3 million for the year ended December 31, 2016. The decrease of $0.7 million in cash used is primarily due to a decrease in cash used for accounts payable of $1.8 million in 2017, which was mostly offset by an increase of $1.0 million in acquisition related expenses in 2017.

Investing Activities

Net cash provided by investing activities was $1.0 million for the year ended December 31, 2017, as compared with $0.2 million for the same period in 2016. For the 2017 period, the Company received $2.0 million for the sale of the Hydro Resources, Inc. properties, advanced $0.8 million to Alabama Graphite Corp. as part of the Arrangement agreement and had purchases of equipment of $0.1 million. For the 2016 period, the Company received $0.2 million from the sale of short-term investments.

Financing Activities

Net cash provided by financing activities was $11.0 million for the year ended December 31, 2017. During 2017 we received net cash proceeds of $15.5 million from equity financings completed in January, February and September 2017, respectively. Additionally, $1.0 million was received from the sale of common stock sold through the Company’s ATM Offering. This increase was offset by the repayment of $5.5 million outstanding under the RCF Loan.

Net cash provided by financing activities was $14.5 million for the year ended December 31, 2016. During 2016, we received net cash proceeds of $0.8 million and $1.2 million upon closing the February 4, 2016 and April 4, 2016 registered direct offerings, respectively, $6.7 million in net proceeds were received from the sale of common stock to Aspire Capital under the terms of the CSPA and $5.8 million in net proceeds were received from the sale of common stock sold through the Company’s ATM program.

Liquidity and Capital Resources

At December 31, 2017, the Company had working capital of $3.9 million, which along with the anticipated funding from the financing agreements described below is expected to provide it with the necessary liquidity through March 31, 2019. At December 31, 2016, the Company had a working capital deficit of $4.2 million. The increase in working capital of $8.1 million for 2017 was primarily due to the following:

● the completion of three equity offerings in January 2017, February 2017 and September 2017 for net proceeds of $8.9 million, $4.5 million and $2.0 million respectively, as further described under “Recent Developments”;

● the completion of the sale of the Company’s wholly-owned subsidiary HRI to Laramide on January 5, 2017. Upon completion, the Company received (i) $2.2 million in cash, (ii) a $5.0 million promissory note, of which $1.5 million was paid in January 2018, partly in cash and partly in Laramide common shares, (iii) 2,218,333 shares of Laramide’s common stock which had a fair value of $0.9 million at December 31, 2017 and (iv) 2,218,333 common stock purchase warrants which had a fair value of $0.5 million at December 31, 2017. Details regarding this transaction are discussed in Note 3 to the accompanying condensed consolidated financial statements; and

● the repayment of the $5.5 million outstanding balance under the RCF Loan (defined in Note 7 to the accompanying condensed consolidated financial statements.)

Also during 2017, the Company entered into the following financing agreements and anticipates funding from these sources to sustain operations through March 31, 2019:

●

Controlled Equity Offering Sales Agreement with Cantor

On April 14, 2017, the Company entered into the ATM Offering with Cantor acting as sales agent, pursuant to which the Company has registered the offer and sale from time to time of shares of its common stock having an aggregate offering price of up to $30.0 million of which approximately $28.8 million is available for future sales as of March 1, 2018. The Company is unable to sell shares of its common stock through the ATM Offering on dates that it places shares with Aspire Capital through its CSPA, as discussed below.

65

●

Common Stock Purchase Agreement with Aspire

On September 25, 2017, the Company entered into a CSPA with Aspire Capital to place up to $22.0 million in the aggregate of its common stock over a term of 30 months. Upon execution of the CSPA, the Company issued 880,000 shares of common stock to Aspire Capital as a commitment fee. The Company cannot sell in excess of 5,033,677 shares of common stock, the Exchange Cap, including the 880,000 commitment shares, unless (i) stockholder approval is obtained, or (ii) the average price paid for all shares issued under the CSPA (including the 880,000 commitment shares) is equal to or greater than $1.38. As of March 1, 2018, the Company has dollar capacity of $19.8 million of common stock available for future sales, limited to the current Exchange Cap of 2.6 million shares of common stock unless conditions (i) or (ii) above are met. See Note 10 to the accompanying consolidated financial statements for further details.

The Company believes that the ATM Offering and the CSPA, along with its existing working capital balance, will provide it with the necessary liquidity to fund operations through March 31, 2019. The Company will also continue to explore additional opportunities to raise capital, further monetize its non-core assets and identify ways to reduce its cash expenditures.

While the Company has been successful in the past raising funds through equity and debt financings as well as through the sale of non-core assets, no assurance can be given that additional financing will be available to it in amounts sufficient to meet the Company’s needs or on terms acceptable to the Company. In the event that funds are not available, the Company may be required to materially change its business plans.

Off- Balance Sheet Arrangements

We have no off-balance sheet arrangements.

Critical Accounting Policies

Our significant accounting policies are described in Note 1 to the consolidated financial statements in Item 8 of this Annual Report on Form 10-K. We believe our most critical accounting policies involve those requiring the use of significant estimates and assumptions in determining values or projecting future costs.

Property, Plant and Equipment

We review and evaluate our long-lived assets for impairment when events or changes in circumstances indicate that the related carrying amounts may not be recoverable. Impairment is considered to exist if the total estimated future cash flows on an undiscounted basis are less than the carrying amount of the assets. An impairment loss is measured and recorded based on discounted estimated future cash flows or upon an estimate of fair value that may be received in an exchange transaction. Future cash flows are estimated based on estimated quantities of recoverable minerals, expected U3O8 prices (considering current and historical prices, trends and related factors), production levels, operating costs of production, availability and cost of capital and restoration and reclamation costs, based upon the projected remaining future uranium production from each project. The significant assumptions used in determining the future cash flows for our uranium properties and uranium plant assets at December 31, 2017 included an average long-term U3O8 price of $41.34 per pound and average operating costs and capital expenditure costs based on third-party and internal cost estimates. Estimates and assumptions used to assess recoverability of our long-lived assets and measure fair value of our uranium properties are subject to risk uncertainty. Changes in these estimates and assumptions could result in the impairment of our long-lived assets. Events that could result in the impairment of our long-lived assets include, but are not limited to, decreases in the future U3O8 prices, decreases in the estimated recoverable minerals and any event that might otherwise have a material adverse effect on our costs.

During 2017 and 2016, we recorded impairments of $11.4 million and $1.7 million, respectively, to reduce the carrying value of property, plant and mine equipment. Existing proven and probable reserves and value beyond proven and probable reserves, including mineralization that is not part of the measured, indicated or inferred resource base, are included when determining the fair value of uranium properties upon acquisition and, subsequently, in determining whether the assets are impaired. The term “recoverable minerals” refers to the estimated amount of uranium that will be obtained after taking into account losses during processing and treatment. In estimating future cash flows, assets are grouped at the lowest level for which there is identifiable cash flows that are largely independent of future cash flows from other asset groups.

Asset Retirement Obligations

Regarding our reserve for asset retirement obligations, significant estimates were utilized in determining the future costs to complete the groundwater restoration, plugging and abandonment of wellfields and surface reclamation at our ISR sites. Estimating future costs can be difficult and unpredictable as they are based principally on current legal and regulatory requirements and ISR site closure plans that may change materially. The laws and regulations governing ISR site closure and remediation in a particular jurisdiction are subject to review at any time and may be amended to impose additional requirements and conditions which may cause our provisions for environmental liabilities to be underestimated and could materially affect our financial position or results of operations. Estimates of future asset retirement obligation costs are also subject to operational risks such as acceptability of treatment techniques or other operational changes.

ITEM 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

Smaller reporting companies are not required to provide the information required by this item.

66

ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA

REPORTS OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRMS

To the Shareholders and the Board of Directors of

Westwater Resources, Inc.

Opinion on the Financial Statements

We have audited the accompanying consolidated balance sheet of Westwater Resources, Inc. (formally known as Uranium Resources, Inc.) and subsidiaries (the “Company”) as of December 31, 2017, the related consolidated statements of operations, shareholders’ equity, and cash flows for the year then ended, and the related notes. In our opinion, the consolidated financial statements present fairly, in all material respects, the consolidated financial position of the Company as of December 31, 2017, and the consolidated results of its operations and its cash flows for the year then ended, in conformity with accounting principles generally accepted in the United States of America.

Basis for Opinion

These consolidated financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on the Company’s 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.

In our opinion, the consolidated financial statements referred to above present fairly, in all material respects, the financial position of Westwater Resources, Inc. and subsidiaries as of December 31, 2017, and the results of their operations and their cash flows for the year then ended in conformity with accounting principles generally accepted in the United States of America.

/s/ Moss Adams LLP

Denver, Colorado

March 1, 2018

We have served as the Company’s auditor since November 16, 2017.

67

REPORTS OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRMS – (CONTINUED)

To the Board of Directors and Stockholders

Uranium Resources, Inc.

We have audited the accompanying consolidated balance sheets of Westwater Resources, Inc. (formally known as Uranium Resources, Inc.) and subsidiaries (collectively, the “Company”) as of December 31, 2016, and the related consolidated statements of operations, shareholders’ equity, and cash flows for the year then ended. These financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on these financial statements based on our audit.

We conducted our audit 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. The Company is not required to have, nor were we engaged to perform, an audit of its internal control over financial reporting. Our audits included consideration of internal control over financial reporting as a basis for designing audit procedures that are appropriate in the circumstances, 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. An audit also includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements, assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audit provides 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 Westwater Resources, Inc. and subsidiaries as of December 31, 2016, and the results of their operations and their cash flows for the year then ended in conformity with U.S. generally accepted accounting principles.

/s/ Hein & Associates LLP

Denver, Colorado

March 2, 2017

68

WESTWATER RESOURCES, INC.

CONSOLIDATED BALANCE SHEETS

(expressed in thousands of dollars, except share amounts)

	Notes	December 31, 2017			December 31, 2016
ASSETS
Current Assets:
Cash and cash equivalents		$	4,054		$	3,309
Marketable securities	4		1,361			-
Notes receivable - current	3,4		1,750			-
Prepaid and other current assets			668			602
Total Current Assets			7,833			3,911
Property, plant and equipment, at cost:
Property, plant and equipment			101,187			112,964
Less accumulated depreciation and depletion			(65,778	)		(66,048	)
Net property, plant and equipment	5		35,409			46,916
Restricted cash			3,668			3,964
Notes receivable, non-current	3,4		3,328			-
Long-term assets held for sale	4		-			2,123
Total Assets		$	50,238		$	56,914
LIABILITIES AND STOCKHOLDERS’ EQUITY
Current Liabilities:
Accounts payable		$	538		$	610
Accrued liabilities			2,352			1,981
Convertible loan net of discount	6		-			5,431
Current portion of asset retirement obligations	7		1,078			121
Total Current Liabilities			3,968			8,143
Asset retirement obligations, net of current portion	7		4,653			4,668
Other long-term liabilities	8		500			500
Long-term liabilities related to assets held for sale	4		-			555
Total Liabilities			9,121			13,866
Commitments and Contingencies	6,7,8,12,14
Stockholders’ Equity:
Common stock, 100,000,000 shares authorized, $.001 par value; Issued shares - 27,790,324 and 16,675,419, respectively Outstanding shares - 27,782,299 and 16,667,394, respectively	9		28			17
Paid-in capital	9,10		297,250			280,191
Accumulated other comprehensive gain			287			-
Accumulated deficit			(256,190	)		(236,902	)
Less: Treasury stock (8,025 and 8,025 shares, respectively), at cost			(258	)		(258	)
Total Stockholders’ Equity			41,117			43,048
Total Liabilities and Stockholders’ Equity		$	50,238		$	56,914

The accompanying notes are an integral part of these consolidated financial statements.

69

WESTWATER RESOURCES, INC.

CONSOLIDATED STATEMENTS OF OPERATIONS

(expressed in thousands of dollars, except share and per share amounts)

		For the Year Ended December 31,
	Notes	2017			2016
Operating Expenses:
Mineral property expenses	5	$	(4,584	)	$	(3,248	)
General and administrative			(6,614	)		(7,650	)
Acquisition related costs			(1,003	)		-
Accretion of asset retirement obligations	7		(1,039	)		(480	)
Depreciation and amortization			(142	)		(247	)
Impairment of uranium properties	5		(11,436	)		(1,673	)
Total operating expenses			(24,818	)		(13,298	)
Non-Operating Income/(Expenses):
Loss on extinguishment of convertible debt	6		(39	)		(3,322	)
Interest income (expense)	4,6		614			(2,800	)
Commitment fees			-			(333	)
Gain on disposal/exchange of uranium properties	4		4,927			-
Other income/(expense), net			28			148
Total other income/(expense)			5,530			(6,307	)
Net Loss		$	(19,288	)	$	(19,605	)
Other Comprehensive Loss
Unrealized fair value increase (decrease) on available-for-sale securities		$	287		$	(49	)
Transfer to realized gain upon sale of available-for-sale securities			-			116
Comprehensive Loss		$	(19,001	)	$	(19,538	)
BASIC AND DILUTED LOSS PER SHARE		$	(0.78	)	$	(3.73	)
WEIGHTED AVERAGE NUMBER OF SHARES OUTSTANDING			24,736,955			5,251,954

The accompanying notes are an integral part of these consolidated financial statements.

70

WESTWATER RESOURCES, INC.

CONSOLIDATED STATEMENTS OF STOCKHOLDERS’ EQUITY

(expressed in thousands of dollars, except share amounts)

	Common Stock				Paid-In			Accumulated Other Comprehensive			Accumulated			Treasury
	Shares		Amount		Capital			(Loss) Gain			Deficit			Stock			Total
Balances, January 1, 2016		4,522,186	$	5	$	258,096		$	(67	)	$	(217,297	)	$	(258	)	$	40,479
Net loss		-		-		-			-			(19,605	)		-			(19,605	)
Common stock issued, net of issuance costs		8,930,061		9		13,940			-			-			-			13,949
Common stock issued for extinguishment of convertible debt		2,487,562		3		5,820			-			-			-			5,823
Common stock issued for settlement of accounts payable		214,991		-		850			-			-			-			850
Common stock issued for purchase of lithium properties		100,000		-		132												132
Common stock issued for loan interest		83,000		-		304			-			-			-			304
Common stock issued for commitment fees		315,000		-		856			-			-			-			856
Stock compensation expense and related share issuances, net of shares withheld for the payment of taxes		14,594		-		195			-			-			-			195
Minimum withholding taxes on net share settlements of equity awards		-		-		(2	)		-			-			-			(2	)
Unrealized holding gain on available-for-sale securities		-		-		-			67			-			-			67
Balances, December 31, 2016		16,667,394	$	17	$	280,191		$	-		$	(236,902	)	$	(258	)	$	43,048
Net loss												(19,288	)					(19,288	)
Common stock issued, net of issuance costs		9,926,396		10		15,311			-			-			-			15,321
Common stock issued for settlement of accounts payable		177,700		-		325			-			-			-			325
Common stock issued for purchase of lithium properties		100,000		-		110			-			-			-			110
Common stock issued for commitment fees		880,000		1		1,213			-			-			-			1,214
Stock compensation expense and related share issuances, net of shares withheld for the payment of taxes		38,834		-		101			-			-			-			101
Minimum withholding taxes on net share settlements of equity awards		-		-		(1	)		-			-			-			(1	)
Unrealized holding gain on available-for-sale securities		-		-		-			287			-			-			287
Balances, December 31, 2017		27,790,324	$	28	$	297,250		$	287		$	(256,190	)	$	(258	)	$	41,117

The accompanying notes are an integral part of these consolidated financial statements.

71

WESTWATER RESOURCES, INC.

CONSOLIDATED STATEMENTS OF CASH FLOWS AND SUPPLEMENTAL CASH FLOW INFORMATION

(expressed in thousands of dollars)

		For the Year Ended December 31,
	Notes	2017			2016
Operating Activities:
Net loss		$	(19,288	)	$	(19,605	)
Reconciliation of net loss to cash used in operations:
Accretion of asset retirement obligations	7		1,039			480
Decrease in restoration and reclamation accrual	7		(97	)		(54	)
Amortization of debt discount	6		30			1,839
Amortization of convertible loan establishment fee	6		-			100
Amortization of note receivable discount	3,4		(744	)		-
Amortization of non-cash investor relations fee			250			-
Depreciation and amortization			142			247
Stock compensation expense	10		101			195
Common stock issued as payment of commitment fees			-			333
Common stock issued as payment of accounts payable			25			-
Common stock issued for lithium property acquisition			-			278
Impairment of uranium properties	5		11,436			1,673
Gain on disposal of fixed assets			(1	)		-
Gain on sale of uranium properties	4		(4,963	)		-
Loss on extinguishment of convertible debt	6		39			3,322
Loss on sale of marketable securities			-			116
Effect of changes in operating working capital items:
Decrease in receivables			5			89
Decrease in prepaid and other current assets			(22	)		53
Increase/(decrease) in payables, accrued liabilities and deferred credits			445			(1,375	)
Net Cash Used In Operating Activities			(11,603	)		(12,309	)
Cash Flows From Investing Activities:
Purchases of equipment			(100	)		(26	)
Proceeds from disposal of mineral properties, net	4		1,950			-
Proceeds from disposal of property, plant and equipment			1			-
Proceeds from the sale of other short-term assets			-			247
Note advances for Alabama Graphite Corp. acquisition			(833	)		-
Net Cash Provided By Investing Activities			1,018			221
Cash Flows From Financing Activities:
Payments on borrowings			(5,500	)		-
Issuance of common stock, net	9		16,535			14,472
Payment of minimum withholding taxes on net share settlements of equity awards			(1	)		(2	)
Net Cash Provided By Financing Activities			11,034			14,470
Net increase in cash, cash equivalents and restricted cash			449			2,382
Cash, Cash Equivalents and Restricted Cash, Beginning of Period			7,273			4,891
Cash, Cash Equivalents and Restricted Cash, End of Period		$	7,722		$	7,273
Cash Paid During the Period for:
Interest		$	130			600
Supplemental Non-Cash Information with Respect to Investing and Financing Activities:
Common stock issued for payment of accounts payable	9		325			850
Common stock issued for payment of loan interest	6,9		-			304
Common stock issued for payment of commitment fees	9		1,214			523
Total Non-Cash Investing and Financing Activities for the Period		$	1,539		$	1,677

The accompanying notes are an integral part of these consolidated financial statements.

72

WESTWATER RESOURCES, INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

1. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

Change in Corporate Name

Effective August 21, 2017, the Company changed its name from “Uranium Resources, Inc.” to “Westwater Resources, Inc.” The name change was made pursuant to Section 242 of the Delaware General Corporation Law and did not affect the rights of the Company’s security holders.

Principles of Consolidation

The consolidated financial statements have been prepared in accordance with accounting principles generally accepted in the United States of America (“U.S.”) and include the accounts of WWR and its wholly-owned subsidiaries. All significant intercompany transactions have been eliminated in consolidation.

Use of Estimates

The preparation of financial statements in conformity with generally accepted accounting principles in the U.S. (“US GAAP”) requires management to make certain estimates and assumptions. Such estimates and assumptions affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates. The most significant estimates included in the preparation of the financial statements are related to asset retirement obligations; stock-based compensation; derivative liabilities and asset impairment, including estimates used to derive future cash flows or market value associated with those assets.

Cash and Cash Equivalents

We consider all highly liquid investments with a maturity of three months or less when purchased to be cash equivalents. We maintain cash deposits in excess of federally insured limits. We monitor the soundness of the financial institution and believe the risk is negligible.

Available-for-Sale Investments

We determine the appropriate classification of our investments at the time of purchase and re-evaluate such determinations each reporting date. Marketable equity securities are categorized as available-for-sale and carried at fair market value on the Balance Sheet.

Unrealized gains and losses are included as a component of accumulated other comprehensive loss, unless an other-than-temporary impairment in value has occurred in which case the unrealized loss would be charged to current period loss as an impairment charge. Unrealized gains and losses originally included in accumulated other comprehensive income are reclassified to current period net loss when the sale of securities occurs or when a security is impaired.

Property, Plant and Equipment

Facilities and Equipment

Expenditures for new facilities or equipment and expenditures that extend the useful lives of existing facilities or equipment are capitalized and recorded at cost. The facilities and equipment are amortized using the units of production method. During the periods that our facilities are not in production, depreciation of our facilities and equipment is suspended as the assets are not in service.

Mineral Properties

Mineral rights acquisition costs are capitalized when incurred, and exploration costs are expensed as incurred. When we determine that a mineral right can be economically developed in accordance with U.S. GAAP, the costs then incurred to develop such property will be capitalized. During the periods that our facilities are not in production, depletion of our mineral interests, permits, licenses and development properties is suspended as the assets are not in service. If mineral properties are subsequently abandoned or impaired, any non-depleted costs will be charged to loss in that period.

73

WESTWATER RESOURCES, INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

Other Property, Plant and Equipment

Other property, plant and equipment consisted of corporate office equipment, furniture and fixtures and transportation equipment. Depreciation on other property is computed based upon the estimated useful lives of the assets. Repairs and maintenance costs are expensed as incurred. Gain or loss on disposal of such assets is recorded as other income or expense as such assets are disposed.

Asset Impairment

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. Impairment is considered to exist if the total estimated future cash flows on an undiscounted basis are less than the carrying amount of the assets. An impairment loss is measured and recorded based on discounted estimated future cash flows or upon an estimate of fair value that may be received in an exchange transaction. Future cash flows are estimated based on quantities of recoverable minerals, expected uranium prices, production levels and operating costs of production and capital, based upon the projected remaining future uranium production from each project. Existing proven and probable reserves and value beyond proven and probable reserves, including mineralization that is not part of the measured, indicated or inferred resource base, are included when determining the fair value of mine site reporting units at acquisition and, subsequently, in determining whether the assets are impaired. The term “recoverable minerals” refers to the estimated amount of uranium that will be obtained after taking into account losses during processing and treatment. 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 likely that actual future cash flows will be significantly different than the estimates, as actual future quantities of recoverable minerals, uranium prices, production levels and operating costs of production and availability and cost of capital are each subject to significant risks and uncertainties.

Assets held for sale

The Company considers assets to be held for sale when management approves and commits to a formal plan to actively market the assets for sale at a price reasonable in relation to fair value, the asset is available for immediate sale in its present condition, an active program to locate a buyer and other actions required to complete the sale have been initiated, the sale of the asset is expected to be completed within one year and it is unlikely that significant changes will be made to the plan. Upon designation as held for sale, the Company records the carrying value of the assets at the lower of its carrying value or its estimated fair value, less costs to sell.

Cash, Cash Equivalents and Restricted Cash

The following table provides a reconciliation of cash, cash equivalents and restricted cash as reported within the consolidated balance sheet that sum to the total of the same such amounts shown in the statement of cash flows.

	For the years ended December 31,
(thousands of dollars)	2017		2016
Cash and cash equivalents	$	4,054	$	3,309
Restricted cash - pledged deposits for performance bonds		3,668		3,964
Cash, cash equivalents and restricted cash shown in the statement of cash flows	$	7,722	$	7,273

Funds deposited by the Company for collateralization of performance obligations are not available for the payment of general corporate obligations and are not included in cash equivalents. Restricted cash consists of pledged certificates of deposit and money market accounts. The bonds are collateralized performance bonds required for future restoration and reclamation obligations related to our South Texas production properties.

74

WESTWATER RESOURCES, INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

Fair Value of Financial Instruments

Our financial instruments consist of cash equivalents, restricted cash and short-term investments. U.S. GAAP defines “fair value” as the price that would be received to sell an asset or be paid to transfer a liability in an orderly transaction between market participants at the measurement date (exit price) and establishes a fair-value hierarchy that prioritizes the inputs used to measure fair value using the following definitions (from highest to lowest priority):

● Level 1 — Unadjusted quoted prices in active markets that are accessible at the measurement date for identical, unrestricted assets or liabilities.

● Level 2 — Observable inputs other than quoted prices included within Level 1 that are observable for the asset or liability, either directly or indirectly, including quoted prices for similar assets and liabilities in active markets; quoted prices for identical or similar assets and liabilities in markets that are not active; or other inputs that are observable or can be corroborated by observable market data by correlation or other means.

● Level 3 — Prices or valuation techniques requiring inputs that are both significant to the fair-value measurement and unobservable.

The Company considers all highly liquid instruments purchased with an original maturity of three months or less to be cash equivalents. The Company continually monitors its positions with, and the credit quality of, the financial institutions with which it invests. Periodically throughout the year, the Company has maintained balances in various U.S. operating accounts in excess of U.S. federally insured limits.

The following table presents information about financial instruments recognized at fair value on a recurring basis as of December 31, 2017 and 2016, and indicates the fair value hierarchy:

	December 31, 2017
(thousands of dollars)	Level 1		Level 2		Level 3		Total
Current Assets
Short-term available-for-sale investments	$	1,361	$	-	$	-	$	1,361
Total current assets recorded at fair value	$	1,361	$	-	$	-	$	1,361
Non-current Assets
Restricted cash	$	3,668	$	-		-	$	3,668
Total non-current assets recorded at fair value	$	3,668	$	-	$	-	$	3,668

	December 31, 2016
(thousands of dollars)	Level 1		Level 2		Level 3		Total
Non-current Assets
Restricted cash		3,964		-		-		3,964
Total assets recorded at fair value	$	3,964	$	-	$	-	$	3,964

Asset Retirement Obligations

Various federal and state mining laws and regulations require the Company to reclaim the surface areas and restore underground water quality for its ISR projects to the pre-existing or background average quality after the completion of mining. Asset retirement obligations, consisting primarily of estimated restoration and reclamation costs at the Company’s South Texas ISR projects, are recognized in the period incurred and recorded as liabilities at fair value. Such obligations, which are initially estimated based on discounted cash flow estimates using level 3 inputs, are accreted to full value over time through charges to accretion expense. In addition, the asset retirement cost is capitalized as part of the asset’s carrying value and amortized over the life of the related asset. If the Company does not have a recorded value for the related asset, then the asset retirement cost is expensed as incurred. Asset retirement obligations are periodically adjusted to reflect changes in the estimated present value resulting from revisions to the estimated timing or amount of restoration and reclamation costs. As the Company completes its restoration and reclamation work at its properties, the liability is reduced by the carrying value of the related asset retirement liability which is based upon the percentage of completion of each restoration and reclamation activity. Any gain or loss upon settlement is charged to income or expense and is included as part of the Company’s mineral property expense for the period. The Company reviews and evaluates its asset retirement obligations annually or more frequently at interim periods if deemed necessary.

75

WESTWATER RESOURCES, INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

Loss Per Share

Basic loss per share is computed using the weighted-average number of shares outstanding during the period. Diluted loss per share is not presented as the effect on the basic loss per share would be anti-dilutive. At December 31, 2017 and 2016, we had 648,404 and 745,841, respectively, in potentially dilutive securities.

Foreign Currency

The functional currency for the companies recently acquired in the Anatolia Transaction was determined to be the U.S. dollar upon completion of the acquisition since our newly acquired foreign subsidiaries are direct and integral components of WWR and are dependent upon the economic environment of WWR’s functional currency. Accordingly, we have translated our monetary assets and liabilities at the period-end exchange rate and the non-monetary assets and liabilities at historical rates, with income and expenses translated at the average exchange rate for the current period. All translation gains and losses have been included in the current period loss.

Recently Adopted Accounting Pronouncements

In August 2014, the Financial Accounting Standards Board (the “FASB”) issued Accounting Standards Update No. 2014-15 (ASU 2014-15), Disclosure of Uncertainties about an Entity’s Ability to Continue as a Going Concern, which provides guidance on determining when and how to disclose going-concern uncertainties in the financial statements. The new standard requires management to perform interim and annual assessments of an entity’s ability to continue as a going concern within one year of the date the financial statements are issued. An entity must provide certain disclosures if conditions or events raise substantial doubt about the entity’s ability to continue as a going concern. The ASU applies to all entities and is effective for annual periods ending after December 15, 2016, and interim periods thereafter, with early adoption permitted. Upon adopting ASU 2014-15, the Company prepared an annual assessment of its ability to continue as a going concern.

In November 2016, the FASB issued Accounting Standards Update No. 2016-18, Statement of Cash Flows: Restricted Cash, which will require that a statement of cash flows explain the change during period in the total of cash, cash equivalents and amounts generally described as restricted cash or restricted cash equivalents. As a result, amounts generally described as restricted cash and restricted cash equivalents should be included with cash and cash equivalents when reconciling the beginning-of-period and end-of-period total amounts shown on the statement of cash flows. The ASU applies to all entities and is effective for fiscal years beginning after December 15, 2018 and interim periods within those fiscal years beginning after December 15, 2019, with early adoption permitted. Upon adopting ASU 2016-18, the Company has included the restricted cash amount in its beginning-of-period and end-of-period reconciliations of cash on its statement of cash flows and has removed restricted cash releases of $0.3 million and $0.1 million from the investing activities section of the cash flow statement for years ended December 31, 2017 and 2016, respectively.

Recently Issued Accounting Pronouncements

In January 2017, the FASB issued Accounting Standards Update No. 2017-01 (ASU 2017-01), Business Combinations: Clarifying the Definition of a Business, which clarifies the definition of a business when determining whether a company has acquired or sold a business. The ASU applies to all entities and is effective for annual periods ending after December 15, 2017, and interim periods thereafter, with early adoption permitted under certain circumstances. The Company does not believe that the adoption of this guidance will have a material impact on our financial statements.

In February 2016, the FASB issued ASU 2016-02, Leases (Topic 842), which requires lessees to recognize all leases, including operating leases, unless the less is a short-term lease or a land lease for mineral properties. ASU 2016-02 also requires additional disclosures regarding leasing arrangements. ASU 2016-02 is effective for interim periods and fiscal years beginning after December 15, 2018, and early application is permitted. Currently, the only leases we hold are for equipment and office space. We have gathered the necessary information for proper disclosure of the leases once the ASU is effective. We will continue to monitor any new leases to ensure that we have all the information necessary to handle the transition to the new standard and properly report the transactions. We do not anticipate the new standard will affect our net income materially, but will result in additional fixed assets and the related lease liabilities.

76

WESTWATER RESOURCES, INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

In May 2014, the FASB issued Accounting Standards Update (“ASU” 2014-09, “Revenue from Contracts with Customers (Topic 606).” The amendments in ASU 2014-09 affect any entity that either enters into contracts with customers to transfer goods or services or enters into contracts for the transfer of non-financial assets unless those contracts are within the scope of other standards (e.g., insurance contracts or lease contracts). This ASU will supersede the revenue recognition requirements in Topic 605, Revenue Recognition, and most industry-specific guidance, and creates a Topic 606, Revenue from Contracts with Customers. The core principal of the guidance is that an entity should recognize revenue to depict the transfer of the promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services. The amendments are effective for annual reporting periods beginning after December 31, 2017, including interim periods within that reporting period. Early application is not permitted. We have reviewed our contracts as well as our procedures and do not anticipate any changes in the manner or timing which we reflect our revenues. The Company had no revenues during 2017 or 2016.

2. LIQUIDITY

At December 31, 2017, the Company had working capital of $3.9 million, which along with the anticipated funding from the financing agreements described below is expected to provide it with the necessary liquidity through March 31, 2019. At December 31, 2016, the Company had a working capital deficit of $4.2 million. The increase in working capital of $8.1 million for 2017 was primarily due to the following:

● the completion of three equity offerings in January 2017, February 2017 and September 2017 for net proceeds of $8.9 million, $4.5 million and $2.0 million respectively, as further described under “Recent Developments”;

● the completion of the sale of the Company’s wholly-owned subsidiary HRI to Laramide on January 5, 2017. Upon completion, the Company received $2.2 million in cash, a $5.0 million promissory note, of which $1.5 million was paid in January 2018, 2,218,333 shares of Laramide’s common stock which had a fair value of $0.9 million at December 31, 2017 and 2,218,333 common stock purchase warrants which had a fair value of $0.5 million at December 31, 2017. Details regarding this transaction are discussed in Note 4 to the accompanying condensed consolidated financial statements; and

● the repayment of the $5.5 million outstanding balance under the RCF Loan (discussed in Note 7 to the accompanying condensed consolidated financial statements.)

Also during 2017, the Company entered into the following financing agreements and anticipates funding from these sources to sustain operations through March 31, 2019:

●	Controlled Equity Offering Sales Agreement
	On April 14, 2017, the Company entered into the ATM Offering with Cantor acting as sales agent, pursuant to which the Company has registered the offer and sale from time to time of shares of its common stock having an aggregate offering price of up to $30.0 million of which approximately $28.8 million is available for future sales as of March 1, 2018. The Company is unable to sell shares of its common stock through the ATM Offering on dates that it places shares with Aspire Capital through its CSPA, as discussed below.
●	Common Stock Purchase Agreement
	On September 25, 2017, the Company entered into a CSPA with Aspire Capital to place up to $22.0 million in the aggregate of its common stock over a term of 30 months. Upon execution of the CSPA, the Company issued 880,000 shares of common stock to Aspire Capital as a commitment fee. The Company cannot sell in excess of 5,033,677 shares of common stock, the Exchange Cap, including the 880,000 commitment shares, unless (i) stockholder approval is obtained, or (ii) the average price paid for all shares issued under the CSPA (including the 880,000 commitment shares) is equal to or greater than $1.38. As of March 1, 2018, the Company has dollar capacity of $19.8 million of common stock available for future sales, limited to the current Exchange Cap of 2.6 million shares of common stock unless conditions (i) or (ii) above are met. See Note 10 to the accompanying consolidated financial statements for further details.

The Company believes that the ATM Offering and the CSPA, along with its existing working capital balance, will provide it with the necessary liquidity to fund operations through March 31, 2019. The Company will also continue to explore additional opportunities to raise capital, further monetize its non-core assets and identify ways to reduce its cash expenditures.

While the Company has been successful in the past raising funds through equity and debt financings as well as through the sale of non-core assets, no assurance can be given that additional financing will be available to it in amounts sufficient to meet the Company’s needs or on terms acceptable to the Company. In the event that funds are not available, the Company may be required to materially change its business plans.

77

WESTWATER RESOURCES, INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

3. NOTES RECEIVABLE

Alabama Graphite Corp. Note Receivable

In conjunction with the proposed acquisition of with Alabama Graphite Corp., on December 13, 2017, the Company executed a secured convertible non-revolving line of credit agreement (the “Alabama Graphite Loan”), whereby the Company agreed to provide up to USD $2,000,000 to Alabama Graphite for the purpose of funding operations until the merger could be finalized. As of December 31, 2017, the Company has advanced $833,744 on the Loan for principal and accrued interest. Under the terms of the Alabama Graphite Loan, the maturity date was June 30, 2018 and it carries a 3% annual interest rate (payable in shares of Alabama Graphite or cash at the Company’s discretion). The Company can convert the Alabama Graphite Loan into shares of Alabama Graphite common stock at any time prior to the maturity date.

Should the merger be terminated or in the event of a change of control, the Alabama Graphite Loan would become due and payable immediately. The Alabama Graphite Loan is secured against all the assets of Alabama Graphite Corp. and Alabama Graphite Company, Inc.

Upon closing of the pending merger, the Alabama Graphite Loan will become part of the consideration paid for the acquisition and ultimately part of the purchase price allocation to the assets and liabilities of the acquired company. Due to the expected inclusion in the acquisition purchase price, it has been classified as a non-current asset at December 31, 2017.

Laramide Note Receivable

As part of the consideration for the sale of Hydro Resources, Inc., (discussed in Note 4 below), the Company holds a $5.0 million promissory note, secured by a mortgage over the Churchrock and Crownpoint projects. The note has a three-year term and carries an initial interest rate of 5% which then increases to 10% upon Laramide’s decision regarding commercial production at the Churchrock project. Principal payments of approximately $1.5 million are due and payable on January 5 in each of 2018 and 2019, with the balance of $2.0 million due and payable on January 5, 2020. Interest is payable on a quarterly basis, provided however that no interest will be payable until March 31, 2018. Laramide will have the right to satisfy up to half of each of these principal payments by delivering shares of its common stock to the Company, which shares will be valued by reference to the volume weighted average price (“VWAP”) for Laramide’s common stock for the 20 trading days before the respective anniversary of January 5, on which each payment is due. The fair value of the notes receivable was determined using the present value of the future cash receipts discounted at a market rate of 9.5%.

The following tables show the notes receivable, accrued interest and unamortized discount on the Company’s notes receivable as of December 31, 2017. The Company had no notes receivable at December 31, 2016.

	December 31, 2017
(thousands of dollars)	Note Amount		Plus Accrued Interest		Less Unamortized Note Discount			Note Balance per Balance Sheet
Current Assets
Notes receivable Laramide – current	$	1,500	$	250	$	-		$	1,750
Subtotal Notes Receivable – current	$	1,500	$	250	$	-		$	1,750
Non-current Assets
Notes receivable – Laramide – non-current	$	3,500	$	-	$	(1,005	)	$	2,495
Notes receivable – Alabama Graphite Corp.		832		1		-			833
Subtotal Notes Receivable – non-current	$	4,332	$	1	$	(1,005	)	$	3,328
Total Notes Receivable – current and non-current	$	5,832	$	251	$	(1,005	)	$	5,078

Laramide made the first required principal payment on the promissory note in January 2018, consisting of $750,000 in cash and the issuance of 1,982,483 of Laramide’s common shares.

78

WESTWATER RESOURCES, INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

4. ACQUISITIONS AND DISPOSALS

Acquisition of Lithium Properties

On June 20, 2017, the Company acquired its third lithium exploration project through the staking of 9,270 acres of federal placer mining claims within the Railroad Valley of central Nevada. The Company incurred costs of $100,912 for the initial staking of these claims in 2017.

During 2016, the Company staked approximately 11,200 acres of placer mining claims covering a prospective target for lithium-enriched brines in the Columbus Salt Marsh area of west-central Nevada. The target area, known as the Columbus Basin project, is situated within a region of known lithium mineralization and is located approximately 45 miles west of Tonopah, Nevada. Additionally, on March 24, 2017, the Company’s wholly owned subsidiary Lithium Holdings Nevada LLC entered into an option agreement to purchase a block of unpatented placer mining claims covering an area of approximately 3,000 acres within the Columbus Salt Marsh area of Esmeralda County, Nevada. The claims adjoin a portion of the Company’s current property holdings at its Columbus Basin project, expanding the project area within the basin to approximately 14,200 acres. The Company has the right to conduct exploration activities on the claims during the one-year option period. Under the option agreement, the Company may acquire the mineral property claims on or before March 24, 2018 in exchange for 200,000 shares of its common stock and a 1% NSR Royalty on the claims. The Company paid $75,000 for this option, which has been included as exploration expense for the Columbus Basin project.

On September 21, 2016, the Company entered into the Mesa SPA with Mesa to acquire certain placer mining claims comprising the Sal Rica project. The target area is situated within a region of known brine-hosted lithium mineralization and is approximately 25 miles north of the town of Wendover, Utah. The Sal Rica project is comprised of approximately 9,900 acres of placer mining claims covering a prospective target for lithium-enriched brines. Additionally, subsequent to the purchase of these claims from Mesa, the Company staked an additional 3,360 acres of unpatented mining claims within the project area.

Under the terms of the Mesa SPA, the Company acquired a 100% interest in the Sal Rica project, subject to a 2% NSR Royalty, for the following consideration: (i) $50,000 cash paid to Mesa at closing; (ii) 100,000 shares of the Company’s common stock at closing; and (iii) 100,000 shares of the Company’s common stock in October 2017.

Disposal of Hydro Resources, Inc.

On January 5, 2017, Laramide and the Company closed the sale of the Company’s wholly-owned subsidiary HRI, which holds the Churchrock and Crownpoint projects, pursuant to a Share Purchase Agreement (the “Laramide SPA”). Under the terms of the Laramide SPA, executed on April 7, 2016 and amended on December 5, 2016, the Company received the following consideration:

● $2.5 million in cash, of which $0.25 million was paid on October 21, 2016;

● 2,218,333 shares of Laramide common stock and 2,218,333 Laramide common stock purchase warrants. Each common stock purchase warrant entitles the Company to purchase one share of common stock of Laramide at a price of CDN$0.45 for a period of 60 months from the date of closing;

● a $5.0 million promissory note, secured by a mortgage over the projects. The note has a three-year term and carries an initial interest rate of 5% which then increases to 10% upon Laramide’s decision regarding commercial production at the Churchrock project. Principal payments of approximately $1.5 million are due and payable on January 5 in each of 2018 and 2019, with the balance of $2.0 million due and payable on January 5, 2020. Interest is payable on a quarterly basis, provided however that no interest will be payable until March 31, 2018. Laramide will have the right to satisfy up to half of each of these principal payments by delivering shares of its common stock to the Company, which shares will be valued by reference to the volume weighted average price (“VWAP”) for Laramide’s common stock for the 20 trading days before the respective anniversary of January 5, on which each payment is due;

● a retained 4.0% Net Smelter Return Royalty (“NSR Royalty”) on the Churchrock project, which royalty could have been repurchased by Laramide by January 5, 2018 for $4.95 million; and

● an option to purchase Laramide’s La Sal project for $3.0 million and an option to purchase its La Jara Mesa project for $5.0 million, both of which expired on January 5, 2018. Any such exercise by the Company will first result in a reduction of the principal amount due under the promissory note with any remaining portions of the purchase price to be paid in cash by the Company.

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WESTWATER RESOURCES, INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

The divestiture of HRI was accounted for as an asset disposal and the non-cash consideration received from Laramide was recorded at fair value. The fair value of the shares of Laramide common stock received was determined using the closing share price of Laramide’s stock on January 5, 2017. The fair value of the common stock purchase warrants was determined using the Black-Scholes method on April 27, 2017, which was the date that Laramide’s stockholders approved the issuance of the warrants. The fair value of the notes receivable was determined using the present value of the future cash receipts discounted at a market rate of 9.5%. The Company did not record a separate fair value for the options as the exercise of the options would reduce the amount outstanding under the notes receivable. Due to the high degree of uncertainties surrounding future mine development and minerals prices, as well as limited marketability, the Company determined the fair value of the NSR Royalty to be nil. The following fair value amounts were recorded as the purchase consideration:

(thousands of dollars)	Fair Value
Cash, less transaction costs	$	1,950
Laramide common stock		568
Laramide common stock purchase warrants		506
Notes receivable		3,501
Total consideration received	$	6,525

The fair value of the shares of Laramide’s common stock and common stock purchase warrants received were valued using Level 1 inputs of the fair value hierarchy and the fair value of the notes receivable was valued using Level 2 inputs, as defined in Note 1 above.

The Company recorded the following gain on disposal of uranium properties within its Consolidated Statement of Operations:

(thousands of dollars)
Total consideration received	$	6,525
Carrying value of Churchrock project		(2,123	)
Carrying value of other plant and equipment		(31	)
Accounts payable		1
Asset retirement obligation		105
Royalty payable on Churchrock project		450
Gain on disposal of HRI	$	4,927

5. PROPERTY, PLANT AND EQUIPMENT

	Net Property, Plant and Equipment at December 31, 2017
(thousands of dollars)	Turkey		Texas		New Mexico		Corporate		Net book value
Uranium plant	$	-	$	8,304	$	-	$	-	$	8,304
Mineral rights and properties-Uranium		17,968		-		7,806		-		25,774
Other property, plant and equipment		11		1,109		-		211		1,331
Total net book value	$	17,979	$	9,413	$	7,806	$	211	$	35,409

80

WESTWATER RESOURCES, INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

	Net Property, Plant and Equipment at December 31, 2016
(thousands of dollars)	Turkey		Texas		New Mexico		Corporate		Net book value
Uranium plant	$	-	$	8,459	$	-	$	-	$	8,459
Mineral rights and properties-Uranium		17,968		-		19,102		-		37,070
Other property, plant and equipment		22		1,224		-		141		1,387
Total net book value	$	17,990	$	9,683	$	19,102	$	141	$	46,916

Lithium Properties

Railroad Valley project

As discussed in Note 4 above, the Company staked approximately 9,270 acres of federal placer mining claims in June 2017 within the Railroad Valley of Central Nevada. We hold these claims through the payment of annual claim maintenance fees to the U.S. Bureau of Land Management. There are no royalty obligations associated with this project.

Columbus Basin project

As discussed in Note 4 above, the Company staked approximately 14,200 acres of unpatented placer mining claims in July and September 2016 in the Columbus Salt Marsh area of west-central Nevada. We hold these claims through the payment of annual claim maintenance fees to the U.S. Bureau of Land Management. There are no royalty obligations associated with this project.

Sal Rica project

As discussed in Note 4 above, the Company acquired approximately 9,900 acres of unpatented placer mining claims from Mesa. Additionally, subsequent to the purchase of these mining claims from Mesa, the Company staked an additional 3,360 acres of unpatented placer mining claims. We hold these claims through the payment of annual claim maintenance fees to the U.S. Bureau of Land Management. Additionally, the claims purchased from Mesa are subject to a 2% NSR royalty on future production. The remaining claims staked by the Company are not subject to any royalties or work commitments.

Uranium Properties

Temrezli project

As discussed in Note 4 above, the Temrezli project was acquired as part of the Anatolia Transaction. The Company controls five licenses that make up the Temrezli project area that were granted to our Turkey-based subsidiary Adur Madencilik Ltd Sti. by the Turkish General Directorate of Mining Affairs. The granted licenses cover an area of about 13,490 acres. We hold these licenses through the payment of fees to the Turkish government and the fulfillment of certain physical work obligations on an annual basis. Uranium production from the licenses is subject to the payment of a sliding scale royalty, ranging from 2% to 16% depending upon the sales price of uranium, as defined by Turkish mining law. The sliding scale royalty payments are to be made to certain agencies of the local and Turkish governments. A further 1% royalty is payable to the General Directorate of Mining Affairs, who discovered the Temrezli uranium deposit.

Kingsville Dome project

The Kingsville Dome project consists of mineral leases from private landowners on about 2,434 gross and 2,227 net acres located in central Kleberg County, Texas. The leases are held through the payment of annual rents, and the lease provide for the payment of production royalties ranging from 6.25% to 9.375%, based upon uranium sales from the respective leases. The leases have expiration dates ranging from 2000 to 2007 however we continue to hold most of these leases through our ongoing restoration activities. With a few minor exceptions, the leases contain clauses that permit us to extend the leases not held by production by payment of an annual per acre royalty ranging from $10 to $30. We have paid such royalties on all material acreage.

81

WESTWATER RESOURCES, INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

Rosita project

The Rosita project consists of mineral leases from private landowners on about 2,759 gross and net acres located in north-central Duval County, Texas. The Rosita South property consists of mineral leases from private land owners on about 1,795 gross acres and 1,479 net acres located in Duval County near the Company’s Rosita project. The leases provide for the payment to the landowners of sliding scale royalties based on a percentage of uranium sales. Royalty percentages on average increase from 6.25% up to 18.25% when uranium prices reach $80.00 per pound. Under the terms of the leases, the lands can be held after the expiration of the primary and secondary terms, as long as are carrying out restoration and reclamation activities. The leases have primary and secondary terms ranging from 2012 to 2016, and provisions to extend the leases beyond the initial terms. We are holding these leases by payment of rentals ranging from $10 to $30 per acre.

Vasquez project

The Vasquez project is comprised of a mineral lease on 872 gross and net acres located in southwestern Duval County, in South Texas. The primary term expired in February 2008; however we hold the lease by carrying out restoration and reclamation activities. We pay an annual rental fee to the landowner and the lease provides for the payment to the landowner royalties based upon 6.25% of uranium sales below $25.00 per pound and royalty rate increases on a sliding scale up to 10.25% for uranium sales occurring at or above $40.00 per pound.

Butler Ranch project

The Butler Ranch project was acquired as part of the Company’s Asset Exchange Agreement with Rio Grande Resources Corporation in November 2014. The property is comprised of fee leases that cover an area of about 990 acres of mineral rights. We can hold the leases by payment of annual rental fees, ranging from $10 to $25 per acre. Each of the leases makes provision for the payment of royalties of 10% of sales to the property owners. Leases have initial terms of 8 to 10 years and have provisions to “hold by drilling” and identifying uranium mineralization on the specific properties. During 2017, all of the Butler Ranch mineral leases were up for renewal. Several land owners opted not to renew, resulting in a drop of acreage from approximately 1,542 to the current 990.

Cebolleta project

In connection with the merger of Neutron (and its wholly-owned subsidiary Cibola Resources LLC (“Cibola”)) we acquired the Cebolleta Lease with La Merced del Pueblo de Cebolleta (the “Cebolleta Land Grant”), a privately held land grant, to lease the Cebolleta project, which is composed of approximately 6,717 acres of fee (deeded) surface and mineral rights. The Cebolleta Lease was affirmed by the New Mexico District Court in Cibola County in April 2007. The Cebolleta Lease provides for: (i) a term of ten years and so long thereafter as Cibola is conducting operations on the Cebolleta property; (ii) initial payments to the Cebolleta Land Grant of $5,000,000; (iii) a recoverable reserve payment equal to $1.00 multiplied by the number of pounds of recoverable uranium reserves upon completion of a feasibility study to be completed within six years, less (a) the $5,000,000 referred to in (ii) above, and (b) not more than $1,500,000 in annual advance royalties previously paid pursuant to (iv); (iv) annual advanced royalty payments of $500,000; (v) gross proceeds royalties ranging from 4.50% to 8.00% based on the then current price of uranium; (vi) employment opportunities and job-skills training for the members of the Cebolleta Land Grant and (vii) funding of annual higher education scholarships for the members of the Cebolleta Land Grant. The Cebolleta Lease provides us with the right to explore for, mine, and process uranium deposits present on the Cebolleta project. In February 2012, we entered into an amendment of the Cebolleta Lease (the “Cebolleta Lease Amendment”) amending the Cebolleta Lease, subject to approval of the Thirteenth Judicial District. Pursuant to the Cebolleta Lease Amendment, the date for the completion of the feasibility study was extended from April 2013 to April 2016. In addition, the date has been further extended subject to a reduction in the $6,500,000 initial payment and annual advance royalty payments deductions to the recoverable reserve payment. The most recent negotiations have resulted in a reduction of the advance royalty payment to $350,000 for three years, after which the payments return to the prior formula. Additionally, and for the duration of the agreement, the requirement for a feasibility report has been removed, the reserve payment has been eliminated in favor of a single payment of $4.0 million upon commencement of production and the gross proceeds royalty has been fixed at 5.75%.

Juan Tafoya project

In connection with the merger with Neutron we acquired the fee interest in 4,097 acres in northwestern New Mexico of fee (deeded) surface and mineral rights owned by the Juan Tafoya Land Corporation (“JTLC”) and 24 leases with private owners of small tracts covering a combined area of 115 acres.

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WESTWATER RESOURCES, INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

The JTLC lease (the “JT Lease”) has a term of ten years, and it can be extended on a year-to-year basis thereafter, so long as we are conducting operations on the Juan Tafoya project. Additionally, the JT Lease required: (i) an initial payment to JTLC of $1,250,000; (ii) annual rental payments of $225,000 for the first five years of the lease and $337,500 for the second five years; (iii) after the second five years, annual base rent of $75 per acre; (iv) a gross proceeds royalty of 4.65% to 6.5% based on the prevailing price of uranium; (v) employment opportunities and job-skills training programs for shareholders of the JTLC or their heirs, (vi) periodic contributions to a community projects fund if mineral production commences from the Juan Tafoya project and (vii) funding of a scholarship program for the shareholders of the JTLC or their heirs. We are obligated to make the first ten years’ annual rental payments notwithstanding the right to terminate the JT Lease at any time, unless (a) the market value of uranium drops below $25 per pound, (b) a government authority bans uranium mining on the Juan Tafoya project, or (c) the project is deemed uneconomical by an independent engineering firm. The Company intends to negotiate with the JTLC on the terms for the continuation of the JT Lease. Our most recent negotiations, completed in the fall of 2017, allow for a reduction of advance royalty payments to $174,000 per annum for three years, after which they return to the original formula. Additionally, the gross proceeds royalty rate is fixed at 4% for the remainder of the agreement.

Impairment of Property, Plant and Equipment

The Company recorded the following impairment charges for 2017 and 2016 related to its uranium projects and processing facilities:

	For the years ended December 31,
	2017		2016
	(thousands of dollars)
Kingsville Dome project	$	140	$	160
Butler Ranch project		-		579
Sejita Dome project		-		534
Nell project		-		209
Jack Pump project		-		191
Cebolleta/Juan Tafoya project		11,296		-
Total Impairment	$	11,436	$	1,673

The significant assumptions used in determining the future cash flows for our uranium properties and uranium plant assets at December 31, 2017 included an average long-term U3O8 price of $41.34 per pound and average operating costs and capital expenditure costs based on third-party and internal cost estimates. Estimates and assumptions used to assess recoverability of our long-lived assets and measure fair value of our uranium properties are subject to risk uncertainty. Changes in these estimates and assumptions could result in the impairment of our long-lived assets. Events that could result in the impairment of our long-lived assets include, but are not limited to, decreases in the future U3O8 prices, decreases in the estimated recoverable minerals and any event that might otherwise have a material adverse effect on our costs.

Existing proven and probable reserves and value beyond proven and probable reserves, including mineralization that is not part of the measured, indicated or inferred resource base, are included when determining the fair value of uranium properties upon acquisition and, subsequently, in determining whether the assets are impaired. The term “recoverable minerals” refers to the estimated amount of uranium that will be obtained after taking into account losses during processing and treatment. In estimating future cash flows, assets are grouped at the lowest level for which there is identifiable cash flows that are largely independent of future cash flows from other asset groups.

The Company’s recorded impairment charge for 2017 of $11.3 million on its Cebolleta/Juan Tafoya project was the result of declining uranium prices as the carrying value exceeded the projects cash flows on an undiscounted and discounted basis. The net carrying value of the Cebolleta/Juan Tafoya project after impairment is $7.8 million at December 31, 2017.

The Company’s recorded impairment charge for 2017 and 2016 of $0.1 million and $0.2 million, respectively, on its Kingsville Dome project was due to the physical deterioration of its processing plant equipment resulting from the plant’s idled status and its proximity to the Texas coastline.

The Company’s recorded impairment charge for 2016 of $0.6 million on its Butler Ranch project was the result of declining uranium prices. During 2016, the carrying value exceeded the projects cash flows on an undiscounted and discounted basis. As a result, the entire carrying value of the Butler Ranch project was written to nil as it was determined that the entire investment was unrecoverable.

83

WESTWATER RESOURCES, INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

The Company’s recorded impairment charges for 2016 of $0.5 million on its Sejita Dome project, $0.2 million on its Nell project and $0.2 million on its Jack Pump project were the result of WWR’s Board of Directors and management determining that exploration results indicated that these projects should be terminated.

Mineral Property Expenses

During the years ending December 31, 2017 and 2016, the Company’s mineral property expenses were $4.6 million and $3.2 million, respectively. Included within mineral property costs are standby costs for our three idled South Texas ISR projects along with holding, exploration and evaluation costs for all properties. The Company spent the following amounts for each of its material properties:

	For the year ended December 31,
	2017		2016
	(thousands of dollars)
Temrezli project, Turkey	$	261	$	498
Total Turkey projects		261		498
Kingsville Dome project, Texas		810		779
Rosita project, Texas		590		402
Vasquez project, Texas		572		461
Butler Ranch project, Texas		21		12
Other projects, Texas		50		94
Total Texas projects		2,043		1,748
Crownpoint project, New Mexico		-		5
Churchrock project, New Mexico		-		20
Cebolleta project, New Mexico		538		138
Juan Tafoya project, New Mexico		528		47
Other projects, New Mexico		14		5
Total New Mexico projects		1,080		215
Columbus Basin project, Nevada		866		232
Railroad Valley, Nevada		238		-
Other projects, Nevada		3		31
Total Nevada projects		1,107		263
Sal Rica project, Utah		93		524
Total Utah projects		93		524
Total expense for the period	$	4,584	$	3,248

6. CONVERTIBLE LOAN

On November 13, 2013, the Company entered into a loan agreement (the “RCF Loan”) with Resource Capital Fund V L.P. (“RCF”), whereby RCF agreed, subject to the terms and conditions set forth in the RCF Loan, to provide a secured convertible loan facility of up to $15.0 million to the Company, which was subsequently amended on April 29, 2014 to reduce the amount available thereunder from $15.0 million to $8.0 million. The Company exchanged $2.5 million in principal for its common shares in December 2016 and repaid the remaining $5.5 million outstanding under the RCF Loan on February 9, 2017. No further obligations remain under the RCF Loan following the repayment.

As a result of the repayment, the Company recorded a loss of $39,000 on the extinguishment of debt which represented the difference between the principal amount of $5.5 million and the carrying value of the RCF Loan on the date of repayment.

84

WESTWATER RESOURCES, INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

7. ASSET RETIREMENT OBLIGATION

The Company’s mining and exploration activities are subject to various state and federal law and regulations governing the protection of the environment. The Company conducts its operations to protect public health and the environment and believes its operations are in compliance with the applicable laws and regulations in all material respects. The Company has made, and expects to make in the future, expenditures to comply with such laws and regulations, but cannot predict the full amount of such future expenditures. Estimated future restoration and reclamation costs are based principally on legal and regulatory requirements.

Changes to the Company’s asset retirement obligation are summarized below:

	December 31, 2017			December 31, 2016
	(thousands of dollars)
Balance, beginning of period	$	4,789		$	4,468
Liabilities settled		(97	)		(54	)
Accretion expense		1,039			480
Balance, end of period		5,731			4,894
Less: Included in liabilities held for sale		-			(105	)
Less: Current portion		(1,078	)		(121	)
Non-current portion	$	4,653		$	4,668

As of December 31, 2017, the Company’s asset retirement obligation was fully secured by surety bonds totaling $9.1 million, which were partially collateralized with restricted cash totaling $3.7 million.

8. OTHER LONG-TERM LIABILITIES

Other long-term liabilities and deferred credits on the balance sheet consisted of:

	December 31,
	2017		2016
	(thousands of dollars)
Royalties payable(1)	$	500	$	500
	$	500	$	500

(1) Royalties payable were derived during prior years of production. Liabilities do not accrue interest or have a stated maturity date.

9. STOCKHOLDERS’ EQUITY

Common Stock Issued, Net of Issuance Costs

Confidentially Marketed Public Offering

On January 19, 2017, the Company completed a registered public offering for net proceeds of $8.9 million. The Company sold 1,399,140 shares of common stock at a price of $2.01 per share and 3,426,731 pre-funded warrants at a price of $2.00 per warrant. The warrants have an exercise price of $0.01. All of the pre-funded warrants have been exercised.

85

WESTWATER RESOURCES, INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

Registered Direct Offering

On February 16, 2017, the Company completed a registered direct offering for net proceeds of $4.5 million with Aspire Capital whereby Aspire Capital purchased 2,100,000 shares of common stock at a price of $1.58 and 748,101 pre-funded common stock purchase warrants at a price of $1.57. The warrants have an exercise price of $0.01 per share and a term of three years. All of the pre-funded warrants have been exercised.

Controlled Equity Offering Sales Agreement

On April 14, 2017, the Company entered into the ATM Offering with Cantor acting as sales agent. Under the ATM Offering, the Company may from time to time sell shares of its common stock having an aggregate offering amount up to $30.0 million in “at-the-market” offerings, which shares are registered under a registration statement on Form S-3, which was declared effective on March 9, 2017. The Company pays Cantor a commission equal to 2.5% of the gross proceeds from the sale of any shares pursuant to the ATM Offering. As of March 1, 2018, the Company had sold 812,723 shares of common stock for net proceeds of $1.2 million under the ATM Offering. As a result, the Company had approximately $28.8 million remaining available for future sales under the ATM Offering. The Company’s previous ATM Offering with BTIG LLC (the “ATM Sales Agreement”) was fully utilized as of December 31, 2016.

Common Stock Purchase Agreement with Aspire Capital

On September 25, 2017, the Company entered into the CSPA with Aspire Capital to place up to $22.0 million in the aggregate of the Company’s common stock on an ongoing basis when required by the Company over a term of 30 months. The Company will control the timing and amount of sales to Aspire Capital, and at a price based on market prices at that time. As consideration for Aspire Capital entering into the purchase agreement, the Company issued 880,000 shares of its common stock to Aspire Capital. The shares of common stock subject to the CSPA were registered pursuant to the Company’s effective shelf registration statement on Form S-3. The parties terminated the April 8, 2016 CSPA with Aspire Capital upon entering into the September 25, 2017 CSPA.

On September 27, 2017, pursuant to the CSPA and after satisfaction of certain commencement conditions, Aspire Capital made an initial purchase of 1,428,571 shares of common stock for which the Company received proceeds of $2.0 million. Additionally, on December 14, 2017, Aspire purchased 150,000 shares of common stock for which the Company received proceeds of $0.2 million. There were no other sales of common stock pursuant to the CSPA and as of March 01, 2018, $19.8 million of the aggregate $22.0 million remained available for future sales under the CSPA.

Common Stock Issued for Investor Relations Fees

On February 28, 2017, the Company issued 150,000 shares with a fair market value of $0.3 million or $2.00 per share as partial consideration for investor relations services that will be provided to the Company over the ensuing 12 months.

Reverse Stock Split

Immediately following the close of trading on March 7, 2016, the Company effected a one-for-twelve reverse stock split of its common stock. With the reverse stock split, every twelve shares of the Company’s issued and outstanding common stock were combined into one issued and outstanding share of common stock. The reverse stock split reduced the number of shares outstanding from approximately 61.8 million shares to approximately 5.2 million shares. In addition, effective upon the reverse stock split, the number of authorized shares of the Company’s common stock was reduced from 200 million to 100 million. The reverse stock split did not have any effect on the par value of the Company’s common stock. No fractional shares were issued as a result of the reverse stock split. Any fractional shares that would have resulted were settled in cash. All share data herein has been retroactively adjusted for the reverse stock split.

Registered Direct Offerings

On February 3, 2016, WWR and Aspire Capital entered into a stock purchase agreement whereby WWR sold 296,666 shares of its common stock in a registered direct offering for gross and net proceeds of $0.8 million. There were no underwriting discounts or placement agent fees.

86

WESTWATER RESOURCES, INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

On April 4, 2016, WWR and Aspire Capital completed a registered direct offering whereby WWR sold 375,000 shares of its common stock at a price of $2.17 per share and 200,000 pre-funded common stock purchase warrants at a price of $2.16 per warrant, which was paid at closing. Gross proceeds from the offering were $1.2 million, including $0.4 million from the sale of the pre-funded warrants. The warrants have an exercise price of $0.01 per share and a term of three years. On June 3, 2016, Aspire Capital exercised all outstanding common stock purchase warrants and the Company issued 200,000 shares of common stock to Aspire Capital as a result.

Option Agreement

On February 3, 2016, the Company issued 75,000 shares of common stock, with a fair value on the date of issuance of $0.3 million, to Aspire Capital as consideration for Aspire Capital entering into an option agreement (the “Option Agreement”) by which Aspire Capital granted the Company the right at any time or times prior to April 30, 2017 to require Aspire Capital to enter into up to two common stock purchase agreements, each having a term of up to 24 months and collectively requiring Aspire Capital to purchase up to $10 million in the aggregate of our common stock at such times and in such amounts as elected by the Company under the terms of the option agreement. The parties terminated the Option Agreement upon entering into the CSPA.

Common Stock Issued for Extinguishment of Debt

As discussed in Note 7, above, on December 5, 2016 the Company issued 2,487,562 shares of its common stock to Esousa in exchange for the retirement of $2.5 million in principal of the Company’s RCF Loan. The exchange was accounted for as an inducement and resulted in the Company recording a $5.8 million increase to additional paid in capital. This $5.8 million increase represents the $2.5 million principal amount that was extinguished and the $3.3 million loss recorded upon the extinguishment of the debt.

Common Stock Issued for RCF Loan Interest and Fees

As discussed in Note 6 above, unless RCF elects to receive cash, RCF receives common shares of the Company for the payment of interest owing on the RCF Loan. For the year ended December 31, 2016, the Company issued 38,086 shares of common stock for the payment of $0.2 million in accrued interest and fees.

On December 5, 2016, the Company issued 44,914 shares to Esousa for the payment of interest owing on the $2.5 million in principal amount of the RCF Loan that Esousa purchased from RCF. The fair value of the shares issued was $61,981 which has been included in interest expense.

Common Stock Issued for Purchase of Lithium Properties

As discussed in Note 5, above, the Company entered into the Mesa SPA on September 21, 2016 to acquire certain placer mining claims comprising the Sal Rica project. Under the terms of the Mesa SPA, the Company issued 100,000 shares of common stock with a fair value of $0.1 million to Mesa upon closing which occurred on October 19, 2016.

Common Stock Issued for fees related to the Anatolia Transaction

On January 8, 2016, the Company issued 117,097 shares of common stock with a fair market value per share of $6.00 in satisfaction of $0.7 million in required termination payments related to the Anatolia Transaction.

On June 30, 2016, the Company issued 47,229 shares of common stock with a fair market value per share of $1.60 in satisfaction of $0.1 million in fees related to the Anatolia Transaction.

On August 1, 2016, the Company issued 50,665 shares of common stock with a fair market value per share of $1.42 in satisfaction of $0.1 million in required termination payments related to the Anatolia Transaction.

87

WESTWATER RESOURCES, INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

10. STOCK BASED COMPENSATION

Stock-based compensation awards consist of stock options, restricted stock units, restricted stock awards and bonus shares issued under the Company’s equity incentive plans which include: the 2013 Omnibus Incentive Plan (the “2013 Plan”); the 2007 Restricted Stock Plan (the “2007 Plan”); the Amended and Restated 2004 Directors’ Stock Option and Restricted Stock Plan (the “2004 Directors’ Plan”); and the 2004 Stock Incentive Plan (the “2004 Plan”). Upon approval of the 2013 Plan by the Company’s stockholders on June 4, 2013, the Company’s authority to grant new awards under all plans other than the 2013 Plan was terminated. On July 18, 2017, the Company’s stockholders approved an amendment to the 2013 Plan to increase the authorized number of shares of common stock available and reserved for issuance under the 2013 Plan by 1.0 million shares and re-approve the material terms of the performance goals under such plan. Under the 2013 Plan, the Company may grant awards of stock options, stock appreciation rights, restricted stock awards (“RSAs”), restricted stock units (“RSUs”), unrestricted stock, dividend equivalent rights, performance shares and other performance-based awards, other equity-based awards and cash bonus awards to eligible persons. The maximum number of the Company’s common stock that may be reserved for issuance under the 2013 Plan is 1,000,000 shares of common stock, plus unissued shares under the prior plans. Equity awards under the 2013 Plan are granted from time to time at the discretion of the Compensation Committee of the Board (the “Committee”), with vesting periods and other terms as determined by the Committee with a maximum term of 10 years. The 2013 Plan is administered by the Committee, which can delegate the administration to the Board, other Committees or to such other officers and employees of the Company as designated by the Committee.

As of December 31, 2017, 561,232 shares of common stock were available for future issuances under the 2013 Plan. For the years ended December 31, 2017 and 2016, the Company recorded stock-based compensation cost of $0.1 million and $0.2 million, respectively, which has been included in general and administrative expense.

In addition, upon completion of the Anatolia Transaction, the Company issued 374,749 replacement options and performance shares to the option holders and performance shareholders of Anatolia Energy. The number of replacement options and performance shares was based upon the Black-Scholes value with the exercise prices of the replacement options and performance shares determined using the exchange rate of 0.00548. The options and performance shares were issued with the same terms and conditions as were applicable prior to the Anatolia Transaction. As of December 31, 2017, there were 90,828 replacement options outstanding.

Bonus Shares

In March 2016, in accordance with the Company’s 2013 Plan, the Company awarded its executives bonuses that were paid out in common stock of the Company. The bonus shares were valued using the closing share price of the Company’s common stock on the date of grant. The bonus shares vested immediately and had a grant date fair value of $0.3 million.

Stock Options

Stock options are valued using the Black-Scholes option pricing model on the date of grant. The Company estimates forfeitures based on historical trends. There were no stock option grants during 2016.

The following table summarizes stock options outstanding and changes during the years ended December 31, 2017 and 2016:

	December 31, 2017					December 31, 2016
	Number of Stock Options			Weighted Average Exercise Price		Number of Stock Options			Weighted Average Exercise Price
Stock options outstanding at beginning of period		110,828		$	18.24		326,424		$	24.89
Granted		189,164			1.40		-			-
Expired		(13,818	)		50.88		(210,872	)		19.13
Canceled or forfeited		-			-		(4,724	)		438.89
Stock options outstanding at end of period		286,174		$	5.53		110,828		$	18.24
Stock options exercisable at end of period		97,010		$	13.59		110,723		$	18.22

88

WESTWATER RESOURCES, INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

The following table summarizes stock options outstanding and exercisable by stock option plan at December 31, 2017:

	Outstanding Stock Options				Exercisable Stock Options
Stock Option Plan	Number of Stock Options Outstanding		Weighted Average Exercise Price		Number of Stock Options Exercisable		Weighted Average Exercise Price
2004 Plan		4,792	$	35.14		4,792	$	35.14
2004 Directors’ Plan		973		317.14		973		317.14
2013 Plan		189,581		1.48		417		35.88
Replacement Stock Options		90,828		9.09		90,828		9.09
		286,174	$	5.53		97,010	$	13.59

Restricted Stock Units

Time-based and performance-based RSUs are valued using the closing share price of the Company’s common stock on the date of grant. The final number of shares issued under performance-based RSUs is generally based on the Company’s prior year performance as determined by the Committee at each vesting date, and the valuation of such awards assumes full satisfaction of all performance criteria.

The following table summarizes RSU activity for the years ending December 31, 2017 and 2016:

	December 31, 2017					December 31, 2016
	Number of RSUs			Weighted- Average Grant Date Fair Value		Number of RSUs			Weighted- Average Grant Date Fair Value
Unvested RSUs at beginning of period		8,649		$	43.71		32,699		$	34.25
Granted		304,064			1.40		-			-
Forfeited		(34,845	)		5.72		(7,627	)		34.61
Vested		(98,971	)		2.50		(16,423	)		29.09
Unvested RSUs at end of period		178,897		$	1.40		8,649		$	43.71

Restricted Stock Awards

Time-based and performance-based RSAs are valued using the closing share price of the Company’s common stock on the date of grant. Vesting based on performance criteria is generally based on the Company’s performance as determined by the Committee at each vesting date, and the valuation of such grants assumes full satisfaction of all performance criteria. Employee participants who receive restricted stock awards have all of the rights of a shareholder, including the right to vote shares of restricted stock that are the subject of the grant and the right to receive any regular cash dividends paid out of current earnings.

The following table summarizes RSA activity during the years ended December 31, 2017 and 2016:

	December 31, 2017				December 31, 2016
	Number of RSAs		Weighted- Average Grant Date Fair Value		Number of RSAs			Weighted- Average Grant Date Fair Value
Unvested RSAs at beginning of period		-	$	-		1,366		$	40.01
Forfeited		-		-		(410	)		44.84
Vested		-		-		(956	)		37.94
Unvested RSAs at end of period		-	$	-		-		$	-

89

WESTWATER RESOURCES, INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

11. FEDERAL INCOME TAXES

The Company recognizes future tax assets and liabilities for each tax jurisdiction based on the difference between the financial reporting and tax bases of assets and liabilities using the enacted tax rates expected to be in effect when the taxes are paid or recovered. A valuation allowance is provided against net future tax assets for which the Company does not consider the realization of such assets to meet the required “more likely than not” standard.

The Company’s future tax assets and liabilities at December 31, 2017 and 2016 include the following components:

	December 31,
	2017			2016
	(thousands of dollars)
Deferred tax assets:
Non-Current:
Net operating loss carryforwards	$	56,781		$	85,995
Mineral properties		7,237			10,152
Accrued vacation		17			29
Reclamation provision		224			41
Capital loss carryforwards		1,013			618
Restoration reserves		980			1,623
Capitalized transaction costs		912			1,140
Other		4,123			4,072
Deferred tax assets		71,287			103,670
Valuation allowance		(68,121	)		(99,548	)
Net deferred tax assets		3,166			4,122
Deferred tax liabilities:
Non-Current:
Derivatives		(590	)		(956	)
Mineral properties, Turkey		(1,437	)		(1,489	)
Securities		(106	)		-
Property, plant and equipment		(1,033	)		(1,677	)
Deferred tax liabilities		(3,166	)		(4,122	)
Net deferred tax asset (liability)	$	-		$	-

The composition of our valuation allowance by tax jurisdiction is summarized as follows:

	December 31,
	2017		2016
	(thousands of dollars)
United States	$	60,920	$	92,448
Australia		5,187		5,187
Turkey		2,014		1,913
Total valuation allowance	$	68,121	$	99,548

The valuation allowance decreased $31.4 million from the year ended December 31, 2016 to the year ended December 31, 2017. There was an increase in the net deferred tax assets, primarily net operating loss carryforwards (“NOLs”), equity-based compensation and exploration spending on mineral properties. The decrease in net deferred tax assets resulted primarily from expiring US state net operating loss carryforwards and from US tax legislation signed into law on December 22, 2017. The Tax Cuts and Jobs Act (TCJA) reduced the US corporate tax rate to 21% for tax years beginning after December 31, 2017, resulting in a decrease in the net deferred tax assets.

Because we do not believe it is more likely than not that the net deferred tax assets will be realized, we continue to record a 100% valuation against the net deferred tax assets.

90

WESTWATER RESOURCES, INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

At December 31, 2017, we had U.S. net operating loss carryforwards of approximately $245 million, which expire from 2018 to 2037. As a result of the TCJA legislation, U.S. net operating losses generated in years ending after 2017 have an indefinite carryforward rather than the previous 20-year carryforward. This does not impact losses incurred in years ended in 2017 or earlier. The U.S. net operating loss carryforward included approximately $32.8 million in net operating loss carryforwards associated with the Neutron merger. At December 31, 2017, we had U.S. capital loss carryforwards of approximately $1.9 million, which expire from 2021 to 2022. In addition, at December 31, 2017, we had Australian net operating loss carryforwards of $13.5 million, including approximately $13.3 million associated with the Anatolia Transaction, which are available indefinitely, subject to continuing to meet relevant statutory tests, and net operating loss carryforwards in Turkey of approximately $1.7 million, which expire from 2018 to 2021.

Section 382 of the Internal Revenue Code could apply and limit our ability to utilize a portion of the U.S. net operating loss carryforwards. Following the issuance of the Company’s Common Stock in 2001, the Neutron merger in 2012 and the Anatolia Transaction in 2015, the ability to utilize the net operating loss carryforwards will be severely limited on an annual and aggregate basis. A formal Section 382 study is in process; however, the actual usage of US net operating loss carryforwards has not been determined. Similar limitations apply to the state net operating loss carryforwards related to the Neutron acquisition.

For financial reporting purposes, loss from operations before income taxes consists of the following components:

	For the calendar year ended December 31,
	2017			2016
	(thousands of dollars)
United States	$	(18,782	)	$	(18,798	)
Australia		(1	)		(158	)
Turkey		(505	)		(649	)
	$	(19,288	)	$	(19,605	)

A reconciliation of expected income tax on net income at statutory rates is as follows:

	Year ended December 31,
	2017			2016
	(thousands of dollars)
Net loss	$	(19,288	)	$	(19,605	)
Statutory tax rate		34	%		34	%
Tax recovery at statutory rate		(6,558	)		(6,666	)
Foreign tax rate		71			2,073
Change in US tax rates		37,233			-
Mineral property adjustments		-			(6,709	)
Capital loss carryforward adjustment		(44	)		-
Operating loss carryforward adjustment		710			6,707
Nondeductible write-offs		15			1,250
Change in valuation allowance		(31,427	)		3,345
Income tax expense (recovery)	$	-		$	-

We do not have any uncertain tax positions. Should we incur interest and penalties relating to tax uncertainties, such amounts would be classified as a component of the interest expense and operating expense, respectively.

Westwater Resources, Inc., and its wholly owned subsidiaries, files in the U.S. federal jurisdiction and various state jurisdictions. Anatolia Energy Limited and Anatolia Uranium Pty Ltd file in the Australian jurisdiction and Adur Madencilik files in the Turkish jurisdiction.

The years still open for U.S. audit are generally the current year plus the previous three. However, because we have NOLs carrying forward, certain items attributable to closed tax years are still subject to adjustment by applicable taxing authorities through an adjustment to tax losses carried forward to open years.

Certain 2016 amounts have been reclassified to conform to the 2017 presentation.

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WESTWATER RESOURCES, INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

12. COMMITMENTS AND CONTINGENCIES

Environmental Considerations

The Company’s uranium recovery operations are subject to federal and state regulations for the protection of the environment, including water quality. Future closure and reclamation costs are provided for as each pound of uranium is produced on a unit-of-production basis. The Company reviews its reclamation obligations each year and determines the appropriate unit charge. The Company also evaluates the status of current environmental laws and their potential impact on their accrual for costs. The Company believes its operations are compliant with current environmental regulations.

Sales Contracts

In March 2006, the Company first amended its sales contracts with Itochu Corporation (“Itochu”) and UG U.S.A., Inc. (“UG”) that superseded the previously existing contracts. Each contract provides for delivery of one- half of our actual production from our properties in Texas currently owned or hereafter acquired by the Company (excluding two specifically identified large ranch properties in South Texas). Uranium deliveries from the inception of the contracts through December 31, 2016 have totaled approximately 510,000 pounds to Itochu and 480,000 pounds to UG.

13. GEOGRAPHIC AND SEGMENT INFORMATION

We currently operate in two reportable segments, which are uranium and lithium mining activities, including exploration, standby operations and restoration and reclamation activities. As a part of these activities, the Company also explores, evaluates and, if warranted, permits uranium and lithium properties. At December 31, 2017, the long-term assets located in the United States totaled $24 million or 58% of our total long-term assets of $42 million. We reported no revenues during the years ended December 31, 2017 and 2016.

The reportable segments are those operations whose operating results are reviewed by the Chief Executive Officer to make decisions about resources to be allocated to the segment and assess its performance provided those operations pass certain quantitative thresholds. Operations whose revenues, earnings or losses or assets exceed or are expected to exceed 10% of the total consolidated revenue, earnings or losses or assets are reportable segments. Information about current assets and liabilities of the segment has not been provided because the information is not used to assess performance.

Non-mining activities and other administrative operations are reported in the Corporate column. The table below provides a breakdown of the long-term assets by geographic segments:

	December 31, 2017
(thousands of dollars)	Corporate		Uranium		Lithium		Total
Net property, plant and equipment	$	211	$	35,198	$	-	$	35,409
Restricted cash		-		3,668		-		3,668
Notes receivable, non-current		834		2,494		-		3,328
Total long-term assets	$	1,045	$	41,360	$	-	$	42,405

	December 31, 2016
(thousands of dollars)	Corporate		Uranium		Lithium		Total
Net property, plant and equipment	$	141	$	46,775	$	-	$	46,916
Restricted cash		-		3,964		-		3,964
Long-term assets held for sale		-		2,123		-		2,123
Total long-term assets	$	141	$	52,862	$	-	$	53,003

92

WESTWATER RESOURCES, INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

The following table provides a breakdown of our operating results by geographic segments for the years ended December 31, 2017 and 2016. All intercompany transactions have been eliminated.

	Year Ended December 31, 2017
(thousands of dollars)	Corporate			Uranium			Lithium			Total
Statement of Operations
Mineral property expenses	$	-		$	3,383		$	1,201		$	4,584
General and administrative		4,783			1,831			-			6,614
Acquisition related expenses		1,003			-			-			1,003
Accretion of asset retirment costs		-			1,039			-			1,039
Depreciation and amortization		5			137			-			142
Impairment of Uranium properties		-			11,436			-			11,436
		5,791			17,826			1,201			24,818
Loss from operations		(5,791	)		(17,826	)		(1,201	)		(24,818	)
Other income (expense)		585			4,944			1			5,530
Loss before taxes	$	(5,206	)	$	(12,882	)	$	(1,200	)	$	(19,288	)

	Year Ended December 31, 2016
(thousands of dollars)	Corporate			Uranium			Lithium			Total
Statement of Operations
Mineral property expenses	$	-		$	2,441		$	807		$	3,248
General and administrative		5,573			2,077			-			7,650
Accretion of asset retirment costs		-			480			-			480
Depreciation and amortization		8			239			-			247
Impairment of Uranium properties		-			1,673			-			1,673
		5,581			6,910			807			13,298
Loss from operations		(5,581	)		(6,910	)		(807	)		(13,298	)
Other income (expense)		(6,339	)		32			-			(6,307	)
Loss before taxes	$	(11,920	)	$	(6,878	)	$	(807	)	$	(19,605	)

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WESTWATER RESOURCES, INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

14. SUBSEQUENT EVENTS

Alabama Graphite Corp. Acquisition

On December 13, 2017, the Company announced that it had entered into a definitive agreement (the “Arrangement Agreement”) with Alabama Graphite Corp. (“Alabama Graphite”), a corporation listed on the TSX Venture Exchange in Toronto (Canada), pursuant to which it is proposed that WWR will acquire all the issued and outstanding securities of Alabama Graphite (the “Acquisition”).

The Acquisition will be by way of a court-approved Plan of Arrangement pursuant to the Business Corporations Act (British Columbia) whereby each issued and outstanding share of Alabama Graphite will be purchased by WWR in exchange for 0.08 of one WWR common share.

Holders of common share purchase warrants and stock options of Alabama Graphite will receive replacement warrants and options issued by WWR. Upon the closing of this transaction the current shareholders of Alabama Graphite will hold approximately 30% of the issued and outstanding shares of WWR.

In addition, on December 13, 2017, the Company agreed to provide a secured loan to Alabama Graphite for up to US$2.0 million to fund Alabama Graphite’s working capital, to pay outstanding trade accounts payable and to provide sufficient operating funds to enable Alabama Graphite to carry on its business until the closing of the Acquisition. The secured loan bears interest at the rate of 3% per annum, is secured by the assets of Alabama Graphite and its subsidiary and is convertible into common shares of Alabama Graphite at WWR’s election using a conversion price of $0.0878, which was determined by calculating the volume-weighted average price (“VWAP”) of the Common Shares for the five trading days immediately following the initial public announcement of the Acquisition (which occurred on December 13, 2017). As of March 1, 2018, the Company has advanced approximately US $1.3 million on the secured Alabama Graphite loan.

Should the Arrangement Agreement be terminated, the secured loan will become payable on June 30, 2018; however, if Alabama Graphite withdraws its support for the Acquisition and recommends a competing transaction, the secured loan becomes repayable immediately. The Arrangement Agreement remains subject to various shareholder and regulatory approvals.

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ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND FINANCIAL DISCLOSURE.

None.

ITEM 9A. CONTROLS AND PROCEDURES

EVALUATION OF DISCLOSURE CONTROLS AND PROCEDURES

The Company maintains disclosure controls and procedures that are designed to ensure that information required to be disclosed in its filings with the SEC is recorded, processed, summarized and reported within the time period specified in the SEC’s rules and forms, and that such information is accumulated and communicated to management, including its Chief Executive Officer and Chief Financial Officer, as appropriate, to allow timely decisions regarding required disclosure. In designing and evaluating the disclosure controls and procedures, management has recognized that any controls and procedures, no matter how well designed and operated, can provide only reasonable assurance of achieving the desired control objectives, and management is required to apply judgment in evaluating its controls and procedures.

During the fiscal period covered by this report, the Company’s management, with the participation of the Chief Executive Officer and Chief Financial Officer of the Company, carried out an evaluation of the effectiveness of the design and operation of the Company’s disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e) of the Securities Exchange Act of 1934, as amended (the “Exchange Act”)). Based on that evaluation, our Chief Executive Officer and Chief Financial Officer have concluded that our disclosure controls and procedures were effective as of December 31, 2017.

MANAGEMENT’S REPORT ON INTERNAL CONTROL OVER FINANCIAL REPORTING

Management of the Company is responsible for establishing and maintaining adequate internal control over financial reporting as defined in Rules 13a-15(f) and 15d-15(f) under the Exchange Act. The Company’s internal control over financial reporting is designed, under the supervision of the Company’s Chief Executive Officer and Chief Financial Officer, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with GAAP. The 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 GAAP, 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.

The Company’s management conducted an evaluation of the effectiveness of the Company’s internal control over financial reporting as of December 31, 2017. This evaluation was based on the framework in Internal Control—Integrated Framework (1992) issued by the Committee of Sponsoring Organizations of the Treadway Commission, or COSO, in 1992. The Company is in the process of adopting the COSO 2013 framework, and management expects to complete the transition from the COSO 1992 framework to the 2013 framework in 2018. All internal control systems, no matter how well designed, have inherent limitations. Therefore, even those systems determined to be effective can provide only reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with GAAP.

Based on management’s evaluation under the framework in Internal Control—Integrated Framework (1992), management concluded that internal control over financial reporting was effective as of December 31, 2017.

This annual report does not include an attestation report of the Company’s independent public accounting firm regarding internal control over financial reporting. Management’s report was not subject to attestation by the Company’s independent public accounting firm pursuant to rules of the SEC that permit the Company to provide only management’s report in this annual report.

95

Changes in Internal Controls over Financial Reporting

There were no changes in the Company’s internal control over financial reporting during the quarter ended December 31, 2017 that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

ITEM 9B. OTHER INFORMATION

None.

PART III

ITEM 10. DIRECTORS, EXECUTIVE OFFICERS AND CORPORATE GOVERNANCE.

This information will be contained in our definitive proxy statement for the 2018 Annual Meeting of Stockholders under the captions “Executives and Executive Compensation—Executive Officers,” “Proposal 2: Election of Directors,” “Section 16(a) Beneficial Ownership Reporting Compliance” and “Corporate Governance” and is incorporated herein by reference.

ITEM 11. EXECUTIVE COMPENSATION

This information will be contained in our definitive proxy statement for the 2018 Annual Meeting of Stockholders under the captions “Executives and Executive Compensation,” “2017 Director Compensation,” “Corporate Governance— Compensation Committee Interlocks and Insider Participation” and “Compensation Committee Report” and is incorporated herein by reference.

ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT AND RELATED STOCKHOLDER MATTERS

This information will be contained in our definitive proxy statement for the 2018 Annual Meeting of Stockholders under the captions “Ownership of WWR Common Stock” and “Securities Authorized for Issuance under Equity Compensation Plans” and is incorporated herein by reference.

ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS, AND DIRECTOR INDEPENDENCE

This information will be contained in our definitive proxy statement for the 2018 Annual Meeting of Stockholders under the captions “Corporate Governance—Director Independence” and “Corporate Governance— Related Party Transactions” and is incorporated herein by reference.

ITEM 14. PRINCIPAL ACCOUNTING FEES AND SERVICES

This information will be contained in our definitive proxy statement for the 2018 Annual Meeting of Stockholders under the captions “Audit and Non-Audit Fees” and “Audit Committee Pre-Approval Policies and Procedures” and is incorporated herein by reference.

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PART IV

ITEM 15. EXHIBITS AND FINANCIAL STATEMENT SCHEDULES

Exhibit Number	Description
1.1	Controlled Equity OfferingSM Sales Agreement, dated April 14, 2017, between the Company and Cantor Fitzgerald & Co. (incorporated by reference to Exhibit 1.1 to the Company’s Current Report on Form 8-K filed on April 17, 2017).
2.1	Arrangement Agreement by and among Westwater Resources, Inc., 1143738 B.C. LTD. and Alabama Graphite Corp. dated as of December 13, 2017 (incorporated by reference to Exhibit 2.1 to the Company’s Current Report on Form 8-K/A filed on January 12, 2018).
3.1	Restated Certificate of Incorporation of the Company, as amended through August 21, 2017 (incorporated by reference to Exhibit 3.1 to the Company’s Quarterly Report on Form 10-Q for the quarterly period ended September 30, 2017).
3.2	Amended and Restated Bylaws of the Company, as amended August 21, 2017 (incorporated by reference to Exhibit 3.2 to the Company’s Quarterly Report on Form 10-Q for the quarterly period ended September 30, 2017).
4.1	Registration Rights Agreement dated as of September 25, 2017, between the Company and Aspire Capital Fund, LLC (incorporated by reference to Exhibit 4.1 to the Company’s Current Report on Form 8-K filed on September 27, 2017).
4.2	Form of options expiring November 28, 2018 (incorporated by reference to Exhibit 4.2 to the Company’s Current Report on Form 8-K filed on December 6, 2016).
4.3	Form of options expiring October 8, 2019 (incorporated by reference to Exhibit 4.3 to the Company’s Current Report on Form 8-K filed on November 13, 2016).
4.4	Form of options expiring January 20, 2020 (incorporated by reference to Exhibit 4.7 to the Company’s Current Report on Form 8-K filed on November 13, 2016).
4.5	Form of options expiring February 28, 2019 (incorporated by reference to Exhibit 4.8 to the Company’s Current Report on Form 8-K filed on November 13, 2016).
4.6	Form of options expiring June 30, 2019 (incorporated by reference to Exhibit 4.11 to the Company’s Current Report on Form 8-K filed on November 13, 2016).
10.1*	Westwater Resources, Inc. 2004 Stock Incentive Plan (incorporated by reference to Exhibit 10.35 to the Company’s Quarterly Report on Form 10-QSB/A for the quarterly period ended September 30, 2005).
10.2*	Amended and Restated 2004 Directors’ Stock Option Plan dated April 10, 2007 (incorporated by reference to Exhibit 10.43 to the Company’s Post- Effective Amendment No. 1 to Registration Statement on Form S-3 filed April 11, 2007, SEC File No. 333-133960)
10.3*	Amended and Restated 2004 Directors’ Stock Option and Restricted Stock Plan dated April 1, 2010 (incorporated by reference to Exhibit 10.43.1 to the Company’s Quarterly Report on Form 10-Q for the quarterly period ended June 30, 2010).
10.4*	Westwater Resources, Inc. 2013 Omnibus Incentive Plan, as amended (incorporated by reference to Appendix B to the Company’s Definitive Proxy Statement on Schedule 14A filed on May 23, 2017).
10.5*	Form of Restricted Stock Agreement under the Company’s 2013 Omnibus Incentive Plan (incorporated by reference to Exhibit 10.2 to the Company’s Current Report on Form 8-K filed on June 7, 2013).
10.6*	Form of Non-Qualified Stock Option Agreement under the Company’s 2013 Omnibus Incentive Plan (incorporated by reference to Exhibit 10.3 to the Company’s Current Report on Form 8-K filed on June 7, 2013).
10.7*	Form of Restricted Stock Unit Agreement under the Company’s 2013 Omnibus Incentive Plan (incorporated by reference to Exhibit 10.4 to the Company’s Current Report on Form 8-K filed on June 7, 2013).
10.8*	Form of Deferred Stock Unit Agreement For Non-Employee Directors under the Company’s 2013 Omnibus0 Incentive Plan (incorporated by reference to Exhibit 10.2 to the Company’s Quarterly Report on Form 10-Q for the quarterly period ended June 30, 2017).

97

10.9*	Employment Agreement, dated March 12, 2013, between the Company and Christopher M. Jones (incorporated by reference to Exhibit 10.2 to the Company’s Quarterly Report on Form 10-Q for the quarterly period ended March 31, 2013).
10.10*	Employment Agreement, effective June 14, 2013, between the Company and Jeffrey L. Vigil (incorporated by reference to Exhibit 10.5 to the Company’s Quarterly Report on Form 10-Q for the quarterly period ended June 30, 2013).
10.11*	First Amendment to Employment Agreement, effective May 22, 2017, between the Company and Jeffrey L. Vigil (incorporated by reference to Exhibit 10.1 to the Company’s Quarterly Report on Form 10-Q for the quarterly period ended June 30, 2017).
10.12	Securities Purchase Agreement, dated as of February 16, 2017, between the Company and Aspire Capital Fund, LLC. (incorporated by reference to Exhibit 10.1 to the Company’s Current Report on Form 8-K filed on February 16, 2017).
10.13	Common Stock Purchase Agreement, dated as of September 25, 2017, between the Company and Aspire Capital Fund, LLC. (incorporated by reference to Exhibit 10.1 to the Company’s Current Report on Form 8-K filed on September 27, 2017).
10.14	Placement Agency Agreement, dated as of January 13, 2017, between the Company and Dawson James Securities, Inc. (incorporated by reference to Exhibit 10.1 to the Company’s Current Report on Form 8-K filed on January 19, 2017).
10.15	Loan Agreement by and among the Company, Alabama Graphite Corp. and Alabama Graphite Company, Inc. dated as of December 13, 2017 (incorporated by reference to Exhibit 2.2 to the Company’s Current Report on Form 8-K filed on December 14, 2017).
10.16	Promissory Note from Alabama Graphite Corp., dated as of December 13, 2017 (incorporated by reference to Exhibit 2.3 to the Company’s Current Report on Form 8-K filed on December 14, 2017).
10.17	Security Agreement by and among the Company, Alabama Graphite Corp. and Alabama Graphite Company, Inc. dated as of December 13, 2017 (incorporated by reference to Exhibit 2.4 to the Company’s Current Report on Form 8-K filed on December 14, 2017).
10.18	Pledge, Security and Subordination Agreement by and between the Company and Alabama Graphite Corp. dated as of December 13, 2017 (incorporated by reference to Exhibit 2.5 to the Company’s Current Report on Form 8-K filed on December 14, 2017).
10.19	Future Advance Mortgage, Assignment of Rents and Leases and Security Agreement made by Alabama Graphite Company, Inc. in favor of the Company, dated as of December 13, 2017 (incorporated by reference to Exhibit 2.6 to the Company’s Current Report on Form 8-K filed on December 14, 2017).
10.20	Assignment of Leases and Agreements made by Alabama Graphite Company, Inc. in favor of the Company, dated as of December 13, 2017 (incorporated by reference to Exhibit 2.7 to the Company’s Current Report on Form 8-K filed on December 14, 2017).
10.21	Form of Voting Agreement by and among 1143738 B.C. LTD., the Company and certain shareholders of Alabama Graphite Corp., each dated as of December 13, 2017 (incorporated by reference to Exhibit 10.1 to the Company’s Current Report on Form 8-K filed on December 14, 2017).
21.1	Subsidiaries of the Registrant.
23.1	Consents of Independent Registered Public Accounting Firms.
31.1	Certification of Chief Executive Officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
31.2	Certification of Chief Financial Officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
32.1	Certification of Chief Executive Officer pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
32.2	Certification of Chief Financial Officer pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
101	The following financial information from the Annual Report on Form 10-K of Westwater Resources, Inc. for the year ended December 31, 2017, formatted in XBRL (extensible Business Reporting Language): (i) Consolidated Statements of Operations, (ii) Consolidated Balance Sheets, (iii) Consolidated Statements of Cash Flows, (iv) Consolidated Statements of Changes in Equity, and (v) Notes to the Condensed Consolidated Financial Statements.

* Indicates management contract or compensatory plan or arrangement.

ITEM 16. FORM 10-K SUMMARY

None.

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SIGNATURES

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.

Date: March 1, 2018

WESTWATER RESOURCES, INC.
By:	/s/ Christopher M. Jones
	Christopher M. Jones, President and Chief Executive Officer

Pursuant to the requirements of the Securities Exchange Act of 1934, this report has been signed below by the following persons on behalf of the Registrant and in the capacities and on the dates indicated.

Signature	Date
/s/ Christopher M. Jones	March 1, 2018
Christopher M. Jones, President, Chief Executive Officer
/s/ Jeffrey L. Vigil	March 1, 2018
Jeffrey L. Vigil, Vice President—Finance and Chief Financial Officer (Principal Financial and Accounting Officer)
/s/ Terence J. Cryan	March 1, 2018
Terence J. Cryan, Chairman
/s/ Marvin K. Kaiser	March 1, 2018
Marvin K. Kaiser, Director
/s/ Tracy D. Pagliara	March 1, 2018
Tracy D. Pagliara, Director
/s/ Patrick N. Burke	March 1, 2018
Patrick N. Burke, Director

99