Confidential draft submitted to the U.S. Securities and Exchange Commission on January 16, 2026
This draft registration statement has not been publicly filed with the U.S. Securities and Exchange Commission and all information herein remains strictly confidential.
This draft registration statement has not been publicly filed with the U.S. Securities and Exchange Commission and all information herein remains strictly confidential.
Registration No. 333-
UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
Confidential Submission No. 2
FORM S-1
REGISTRATION STATEMENT
UNDER
THE SECURITIES ACT OF 1933
UNDER
THE SECURITIES ACT OF 1933
X-Energy, Inc.
(Exact name of registrant as specified in its charter)
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Delaware
(State or other jurisdiction of
incorporation or organization) |
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4911
(Primary Standard Industrial
Classification Code Number) |
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(I.R.S. Employer Identification Number) |
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530 Gaither Road, Suite 700
Rockville, Maryland 20850
(301) 358-5600
Rockville, Maryland 20850
(301) 358-5600
(Address, including zip code, and telephone number, including area code, of registrant’s principal executive offices)
J. Clay Sell
Chief Executive Officer
530 Gaither Road, Suite 700
Rockville, Maryland 20850
(301) 358-5600
Chief Executive Officer
530 Gaither Road, Suite 700
Rockville, Maryland 20850
(301) 358-5600
(Name, address, including zip code, and telephone number, including area code, of agent for service)
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Paul F. Sheridan Jr.
Ian Schuman John Slater Latham & Watkins LLP 555 Eleventh Street, NW Suite 1000 Washington, D.C. 20004 (713) 546-7967 |
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J. Clay Sell
X-Energy, Inc. 530 Gaither Road, Suite 700 Rockville, Maryland 20850 (301) 358-5600 |
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P. Michelle Gasaway
Michael Hong Philip Dear Skadden, Arps, Slate, Meagher & Flom LLP 1000 Louisiana St., Suite 6800 Houston, TX 77002 (713) 655-5190 |
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Approximate date of commencement of proposed sale to the public:
As soon as practicable after the effective date of this registration statement.
As soon as practicable after the effective date of this registration statement.
If any of the securities being registered on this Form are to be offered on a delayed or continuous basis pursuant to Rule 415 under the Securities Act of 1933, as amended, or Securities Act, check the following box: ☐
If this Form is filed to register additional securities for an offering pursuant to Rule 462(b) under the Securities Act, please check the following box and list the Securities Act registration statement number of the earlier effective registration statement for the same offering. ☐
If this Form is a post-effective amendment filed pursuant to Rule 462(c) under the Securities Act, check the following box and list the Securities Act registration statement number of the earlier effective registration statement for the same offering. ☐
If this Form is a post-effective amendment filed pursuant to Rule 462(d) under the Securities Act, check the following box and list the Securities Act registration statement number of the earlier effective registration statement for the same offering. ☐
Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company, or an emerging growth company. See the definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company,” and “emerging growth company” in Rule 12b-2 of the Securities Exchange Act of 1934, as amended.
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Large accelerated filer
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Accelerated filer
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Non-accelerated filer
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Smaller reporting company
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Emerging growth company
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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 7(a)(2)(B) of the Securities Act. ☐
The registrant hereby amends this registration statement on such date or dates as may be necessary to delay its effective date until the registrant shall file a further amendment which specifically states that this registration statement shall thereafter become effective in accordance with Section 8(a) of the Securities Act or until the registration statement shall become effective on such date as the Securities and Exchange Commission, acting pursuant to said Section 8(a), may determine.
TABLE OF CONTENTS
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Neither we nor the underwriters have authorized anyone to provide you with information different from that contained in this prospectus and any free writing prospectus we have prepared. We take no responsibility for, and can provide no assurance as to the reliability of, any other information that others may give you. We and the underwriters are offering to sell Class A common stock and seeking offers to buy Class A common stock only under circumstances and in jurisdictions where such offers and sales are lawful. The information in this prospectus is accurate only as of the date of this prospectus (or as of any earlier date as of which such information is given), regardless of the time of delivery of this prospectus or of any sale of the Class A common stock. Our business, liquidity position, financial condition, prospects or results of operations may have changed since the date of this prospectus.
This prospectus contains forward-looking statements that are subject to a number of risks and uncertainties, many of which are beyond our control. See the sections titled “Risk Factors” and “Cautionary Note Regarding Forward-Looking Statements.”
For investors outside the United States: Neither we nor the underwriters have done anything that would permit a public offering of the securities offered hereby or possession or distribution of this prospectus, any amendment or supplement to this prospectus, or any applicable free writing prospectus in any jurisdiction where action for that purpose is required, other than in the United States. Persons outside the United States who come into possession of this prospectus, any amendment or supplement to this prospectus, or any applicable free writing prospectus must inform themselves about, and observe any restrictions relating to, the offering of the securities and the distribution of this prospectus, any amendment or supplement to this prospectus, or any applicable free writing prospectus outside of the United States.
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EXPLANATORY NOTE
This Registration Statement on Form S-1 is being filed by X-Energy, Inc., a newly formed Delaware corporation, in connection with a proposed registered public offering of shares of its common stock. X-Energy Reactor Company, LLC is the predecessor of the issuer, X-Energy, Inc., for financial reporting purposes. X-Energy, Inc. will be the audited financial reporting entity following this offering. At the time of the initial confidential filing of this registration statement, the audited balance sheet of X-Energy, Inc. has not yet been finalized and is therefore not included in this filing. We intend to amend the registration statement to include all financial information required by Regulation S-X at the date of such amendment before distributing a preliminary prospectus to investors.
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BASIS OF PRESENTATION AND DEFINITIONS
Organizational Structure
In connection with the closing of this offering, we will effect certain organizational transactions. Unless otherwise stated or the context otherwise requires, all information in this prospectus reflects the consummation of the organizational transactions and this offering, which we refer to collectively as the “Transactions.” See “Organizational Structure” for a description of the Transactions and a diagram depicting our organizational structure after giving effect to the Transactions, including this offering.
As used in this prospectus, unless the context otherwise requires, references to:
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“we,” “us,” “our,” the “Company,” “X-energy” and similar references refer, following the consummation of the Transactions, including this offering, to X-Energy, Inc., and, unless otherwise stated, all of its subsidiaries, including X-Energy Reactor Company, LLC, which we refer to as “XERC” and, unless otherwise stated, all of its subsidiaries. When used in a historical context, such terms collectively refer to X-Energy Reactor Company, LLC, which we refer to as “XERC,” our predecessor for financial reporting purposes, and its operating subsidiaries.
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“ARDP” means the U.S. Department of Energy’s Advanced Reactor Demonstration Program.
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“ARDP Agreement” means the Cooperative Agreement between the U.S. Department of Energy and X Energy, LLC, Award No. DE-NE0009040, effective as of February 2, 2021.
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“Basis Adjustments” means the tax basis adjustments, including an increase in X-energy, Inc.’s allocable share of existing tax basis, expected to be obtained by X-energy, Inc. resulting from (a) X-energy Inc’s acquisition of Common Units in connection with this Offering, including the contribution of Common Units from the Continuing Equity Owners, (b) any future redemptions or exchanges of Common Units from the TRA Holders; (c) certain distributions (or deemed distributions) by XERC; and (d) payments made under the Tax Receivable Agreement.
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“Blocker Companies” means entities that are owners of Common Units in XERC prior to the Reorganization Transactions and are taxable as corporations for U.S. federal income tax purposes.
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“Blocker Mergers” means the merger of each of the Blocker Companies with the applicable wholly owned newly formed subsidiaries of X-energy, Inc. as part of the Reorganization Transactions, pursuant to which the Blocker Shareholders receive shares of Class A common stock as consideration for the applicable Blocker Merger.
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“Blocker Shareholders” means the owners of the Blocker Companies prior to the Reorganization Transactions, who will exchange their interests in the Blocker Companies for shares of our Class A common stock in connection with the consummation of the Blocker Mergers.
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“Code” means the U.S. Internal Revenue Code of 1986, as amended.
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“Common Units” means common units of membership interest in X-Energy Reactor Company, LLC.
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“Continuing Equity Owners” refers collectively to those Original Equity Owners (including and each of its permitted transferees) that will own Common Units in XERC after the Reorganization Transactions and who may, following the consummation of this offering, redeem their Common Units for cash or shares of our Class A common stock as described in “Certain Relationships and Related Party Transactions.”
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“DGCL” means the Delaware General Corporation Law, as amended.
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“DOE” means the U.S. Department of Energy.
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“Dow” means Dow Inc. or its subsidiaries.
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“Exchange Act” means the U.S. Securities Exchange Act of 1934, as amended.
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“FOAK” means first-of-a-kind.
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“GAAP” means U.S. generally accepted accounting principles.
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“GFR” means Gas-cooled Fast Reactors.
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“Ghaffarian Enterprises” means Ghaffarian Enterprises, LLC.
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“GM Enterprises” means GM Enterprises, LLC.
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“HALEU” means high-assay low-enriched uranium.
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“HTGR” means High Temperature Gas-cooled Reactors.
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“HTF” means Helium Test Facility.
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“Interest Deductions” means deductions attributable to imputed interest and other payments of interest by X-energy, Inc. pursuant to the Tax Receivable Agreement.
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“LLC Units” means X-Energy Reactor Company, LLC’s existing Common Units and preferred units.
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“MPa” means Megapascal.
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“MSR” means Molten Salt Reactors.
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“NOAK” means Nth-of-a-kind.
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“NRC” means the U.S. Nuclear Regulatory Commission.
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“OPG” means Ontario Power Generation, Inc.
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“Original Equity Owners” refers to the direct and certain indirect owners of XERC, collectively, prior to the Transactions.
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“Person” means any individual, firm, corporation, partnership, limited liability company, incorporated or unincorporated association, joint venture, joint stock company, governmental authority or instrumentality or other entity of any kind.
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“Recapitalization” means the transactions whereby X-Energy Reactor Company, LLC will complete a recapitalization pursuant to which all outstanding equity interests in X-Energy Reactor Company, LLC will be converted or exchanged into Common Units.
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“Reorganization Transactions” means the organizational transactions by which (a) we will become a holding company and the sole managing member of X-Energy Reactor Company, LLC; (b) X-Energy Management, LLC, a Delaware limited liability company (“Management LLC”), will contribute all of its Common Units of X-Energy Reactor Company, LLC to X-energy in exchange for an equal number of shares of X-energy Class A common stock, (c) [each of the X-Energy Holdings, IBX Company Opportunity Fund 1, LP, IBX Company Opportunity Fund 2, LP, IBX Opportunity GP, Inc., X-energy KG Parent, LLC and GM Enterprises] will contribute a portion of their respective Common Units of X-Energy Reactor Company, LLC to X-energy in exchange for an equal number of shares of X-energy Class A common stock; and (d) X-energy will issue Class B common stock to the Continuing Equity Owners in exchange for a nominal cash contribution made by such Continuing Equity Owners, resulting in a combined company organized in an umbrella partnership C corporation (“Up-C”) structure, in which substantially all of the assets and the business of the company will be held by X-Energy Reactor Company, LLC, as more fully described elsewhere in this prospectus.
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“Sarbanes-Oxley Act” means the Sarbanes-Oxley Act of 2002.
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“SEC” means the U.S. Securities and Exchange Commission.
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“Securities Act” means the U.S. Securities Act of 1933, as amended.
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“Series C-1 Investment” means the purchase by the Series C-1 Investors of the Series C-1 Notes.
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“Series C-1 Investors” means those certain investors participating in the Series C-1 Investment.
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“Series C-1 Notes” means the Series C-1 Convertible/Exchangeable promissory notes issued by XERC.
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“Series C-2 Investment” means the purchase by the Series C-2 Investors of the Series C-2 Notes pursuant to the Series C-2 Securities Purchase Agreements.
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“Series C-2 Investors” means those certain investors participating in the Series C-2 Investment.
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“Series C-2 Notes” means the Series C-2 Convertible/Exchangeable promissory notes issued by XERC.
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“Series C-2 Securities Purchase Agreements” means the Series C-2 Convertible/Exchangeable Securities Purchase Agreements entered into between XERC and the Series C-2 Investors.
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“SMR” means Small Modular Reactors.
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“Tax Receivable Agreement” means the Tax Receivable Agreement to be entered into by and among X-energy, XERC and certain Original Equity Owners (the “TRA Holders”) at the consummation of this offering, pursuant to which, among other things, X-energy will be required to pay to each TRA Holder 85% of the amount of cash tax savings, if any, that it realizes (or in certain cases, is deemed to realize) as a result of the Basis Adjustments and Interest Deductions. A copy of the form of Tax Receivable Agreement is attached to this prospectus.
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“TRISO-X” means TRISO-X, LLC, our wholly owned subsidiary.
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“TRISO-X Fuel” refers to the HALEU-based TRISO pebble fuel manufactured for the Xe-100 by our TRISO-X, LLC subsidiary.
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“U.K.” means the United Kingdom.
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“U.S.” means the United States of America.
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“X-energy Founder” means X-Energy Holdings, IBX Company Opportunity Fund 1, LP, IBX Company Opportunity Fund 2, LP, IBX Opportunity GP, Inc., X-energy KG Parent, LLC and GM Enterprises.
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“X-Energy Holdings” means X-Energy Holdings, LLC.
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“XERC LLC Agreement” refers to XERC’s Eighth Amended and Restated Operating Agreement, which will become effective upon the consummation of this offering.
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“XERC” refers to our predecessor for financial reporting purposes, X-Energy Reactor Company, LLC.
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“Xe-100 plant” means the optimized four-reactor configuration of 320 MWe that the Xe-100 is expected to be commonly deployed in.
This prospectus includes certain historical condensed consolidated financial and other data for X-Energy Reactor Company, LLC. Immediately following this offering, we will be a holding company and the sole managing member of XERC, and upon completion of this offering and the application of proceeds therefrom, our principal asset will consist of common units of XERC. We will operate and control all the business and affairs of X-Energy Reactor Company, LLC and conduct our business through X-Energy Reactor Company, LLC and its subsidiaries. Following this offering, X-Energy Reactor Company, LLC will be the predecessor of X-Energy, Inc. for financial reporting purposes. As a result, the consolidated financial statements of X-Energy, Inc. will recognize the assets and liabilities received in the reorganization at their historical carrying amounts, as reflected in the historical financial statements of X-Energy Reactor Company, LLC. We will consolidate X-Energy Reactor Company, LLC on our consolidated financial statements and record a noncontrolling interest related to the LLC Units (as defined below) held by our Continuing Equity Owners (as defined below) on our consolidated balance sheet and statements of operations.
Presentation of Financial and Other Information
XERC is the predecessor of the issuer, X-Energy, Inc., for financial reporting purposes. X-Energy, Inc. will be the audited financial reporting entity following this offering. Accordingly, this prospectus contains the following historical financial statements:
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X-Energy, Inc.: Other than the inception balance sheet, dated as of , the historical financial information of X-Energy, Inc. has not been included in this prospectus as it is a newly incorporated entity, has no business transactions or activities to date and had no assets or liabilities during the periods presented in this prospectus.
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X-Energy Reactor Company, LLC: As we will have no other interest in any operations other than those of X-Energy Reactor Company, LLC and its subsidiaries, the historical consolidated financial information included in this prospectus is that of X-Energy Reactor Company, LLC and its subsidiaries.
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Unaudited Pro Forma Condensed Consolidated Financial Information: This prospectus contains unaudited pro forma condensed consolidated financial information for the year ended December 31, 2024 and as of and for the nine months ended September 30, 2025. The unaudited pro forma condensed consolidated financial information contained in this prospectus is derived from the “Unaudited Pro Forma Condensed Consolidated Financial Information” section of this prospectus. The unaudited pro forma condensed consolidated balance sheet as of September 30, 2025 contained in this prospectus presents the consolidated financial position of XERC after giving effect to the Transactions as if all such transactions had occurred on September 30, 2025 and has been prepared in accordance with Article 11 of Regulation S-X. The unaudited pro forma condensed consolidated statement of operations for the year ended December 31, 2024 and for the nine months ended September 30, 2025 contained in this prospectus presents the consolidated results of operations of XERC after giving effect to the Transactions as if all such transactions had occurred on January 1, 2024 and has been prepared in accordance with Article 11 of Regulation S-X. The unaudited pro forma condensed consolidated financial information is presented for informational purposes only and may not be indicative of the results that would have been achieved if the foregoing transactions had taken place on an earlier date or on the dates assumed. In addition, the unaudited pro forma condensed consolidated financial information does not purport to project the future financial condition and results of operations of XERC or X-Energy, Inc. See “Unaudited Pro Forma Condensed Consolidated Financial Information” for a complete description of the adjustments and assumptions underlying the summary unaudited pro forma condensed consolidated financial data.
Certain monetary amounts, percentages and other figures included in this prospectus have been subject to rounding adjustments. Percentage amounts included in this prospectus have not in all cases been calculated on the basis of such rounded figures, but on the basis of such amounts prior to rounding. For this reason, percentage amounts in this prospectus may vary from those obtained by performing the same calculations using the figures in our consolidated financial statements included elsewhere in this prospectus. Certain other amounts that appear in this prospectus may not sum due to rounding. Figures shown as totals in certain tables or charts may not be the arithmetic aggregation of the figures that precede them, and figures expressed as percentages in the text may not total 100% or, as applicable, when aggregated may not be the arithmetic aggregation of the percentages that precede them.
Our fiscal year begins on January 1 and ends on December 31 of the same year.
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TRADEMARKS, TRADE NAMES AND SERVICE MARKS
We use the X-energy logo and other marks as trademarks in the U.S. and other countries. This prospectus contains references to our trademarks and service marks and to those belonging to other entities. Solely for convenience, trademarks and trade names referred to in this prospectus, including logos, artwork and other visual displays, may appear without the ® or TM symbols, but such references are not intended to indicate in any way that we will not assert, to the fullest extent under applicable law, our rights or the rights of the applicable licensors to these trademarks and trade names. We do not intend our use or display of other entities’ trade names, trademarks or service marks to imply a relationship with, or endorsement or sponsorship of us by, any other entity.
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MARKET AND INDUSTRY DATA
We are responsible for the disclosure contained in this prospectus. Information contained in this prospectus concerning the market and the industry in which X-energy competes, including its market position, general expectations of market opportunity, size and growth rates, is based on information from various third-party sources, X-energy’s knowledge of the markets for its services and solutions, and assumptions made by X-energy based on such sources and knowledge. This information and any estimates provided in this prospectus involve numerous assumptions and limitations, and you are cautioned not to give undue weight to such information. Third-party sources generally state that the information contained in such source has been obtained from sources believed to be reliable but that there can be no assurance as to the accuracy or completeness of such information. Notwithstanding the foregoing, we are liable for the information provided in this prospectus. The industry in which X-energy engages or proposes to engage is subject to a high degree of uncertainty and risk. As a result, the estimates and market and industry information provided in this prospectus are subject to change based on various factors, including those described in the sections of this prospectus entitled “Cautionary Note Regarding Forward-Looking Statements” and “Risk Factors — Risks Related to X-energy — Risks Relating to X-energy’s Business” and elsewhere in this prospectus.
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PROSPECTUS SUMMARY
This summary highlights selected information contained elsewhere in this prospectus and provides an overview of the Company. This summary does not contain all of the information you should consider before investing in our Class A common stock. For a more complete understanding of our business, you should read this entire prospectus carefully, including the sections titled “Risk Factors,” “Management’s Discussion and Analysis of Financial Condition and Results of Operations of X-energy,” “Business” and our audited consolidated financial statements and the related notes included elsewhere in this prospectus, before making an investment decision. Capitalized terms not otherwise defined in this prospectus have the meanings assigned to them under “Basis of Presentation and Definitions” included elsewhere in this prospectus.
Overview
Our company
X-energy is a leading designer of advanced nuclear reactor technology (commonly referred to as small modular reactors, “SMRs”) and manufacturer of advanced nuclear fuels. We believe these scalable, power generation technologies help satisfy historically unprecedented electricity demand growth, driven by the development of AI and associated data center infrastructure. Total demand for new electricity generation is expected to increase globally by 7,626 TWh from 2023 to 2030 and the challenges associated with meeting this demand have led policymakers and industry leaders to recognize nuclear energy, particularly advanced nuclear, as a key component to address this need.
Founded in 2009 by Dr. Kamal “Kam” Ghaffarian to bring clean, safe, secure and affordable technology to market, X-energy is seeking to redefine the energy industry through its flagship product, the Xe-100, an advanced small modular High Temperature Gas-cooled Reactor (“HTGR”), in development for nearly a decade. The Xe-100 reactor is designed to generate 80 megawatts of electric power or 200 megawatts of thermal output (heat), or a combination thereof. This reactor technology builds on more than 50 years of research and development by the global nuclear industry and the operating experience of previous HTGRs including those at Peach Bottom in the U.S., and Dragon in the U.K. in the 1960s-1970s, and more recently with China’s ongoing deployments of HTGRs in the 21st century.
The Xe-100 has several technological attributes that we believe make it advantaged compared to other sources of baseload generation. These include advanced safety features, virtually no direct greenhouse gas (“GHG”) emissions during generation, high thermal output, load-following capabilities and modularity, all of which allow X-energy to more specifically meet a customer’s power and/or industrial heat needs. X-energy’s simple Xe-100 design directly translates into simplicity of project delivery through reduced supply chain complexity and labor intensity during construction, which we believe will lead to lower cost and faster deployment timelines when compared with conventional nuclear energy sources. X-energy has optimized the deployment of its Xe-100 into a four-reactor format that outputs 320 MWe (or 800 MWt). By deploying four independent reactor modules instead of a single unit, this optimized four-reactor configuration inherently delivers the high levels of reliability and redundancy required for both AI and industrial heat applications.
X-energy’s reactors use a tri-structural isotropic (“TRISO”) coated particle fuel in the form of a spherical ‘pebble’, called TRISO-X fuel. This pebble fuel consists of HALEU fuel kernels individually encapsulated in layers of silicon carbide and pyrolytic carbon, forming miniature containment systems that trap fission products. These particles are then embedded in a graphite matrix to make fuel pebbles that possess exceptional safety margins and compacts, enabling operations at very high temperatures. The HALEU fuel used in our TRISO-X pebble fuel is enriched to 15.5%, a higher energy density form than the less than 5% low-enriched uranium (“LEU”) fuel used in conventional nuclear reactors. TRISO-X fuel will be produced at our fuel fabrication facility in Oak Ridge, Tennessee. The first facility, known as TX-1, began construction in October 2024 and is expected to be completed by the first half of 2028 (“TX-1”). Upon completion, it is expected to be North America’s first purpose-built commercial advanced nuclear fuel fabrication facility. The TX-1 facility will have sufficient production capacity to support the fuel needs of the first 11 Xe-100 reactors at steady state operations.
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In addition to its technology leadership, X-energy has three high-quality customers in Dow, Amazon, and Centrica, who we expect will underpin the deployment of the initial fleets of Xe-100 reactors. Taken together, assuming each customer exercises its contingent rights in full, these three customers provide us with a more than 11 gigawatts electric (“GWe”), 144 reactor pipeline across the U.S. and the U.K. with advanced development efforts already underway on the first Dow project at its Seadrift Operations site in Texas and the first Amazon project in connection with Energy Northwest.
X-energy maintains a strong relationship with the DOE and in December 2020 was awarded an initial $1.2 billion project as part of its selection as one of two awardees in the ARDP, the most substantial federal commitment to deploying advanced nuclear technology. The cooperative agreement for the program, signed in March 2021 (the “ARDP Agreement”), provides 50/50 cost share, allowing X-energy to finish the remaining design, licensing, commercialization and construction of its first-of-a-kind commercial advanced nuclear plant and commercial TRISO-X fuel fabrication facility, while benefiting from decades of nuclear experience and knowledge within the DOE.
Our organizational structure following the offering and the Reorganization Transactions is commonly referred to as an umbrella partnership-C corporation (or “Up-C”) structure. Pursuant to this structure, following this offering we will hold a number of XERC Common Units equal to the number of shares of our issued and outstanding Class A common stock, and holders of XERC Common Units (each, an “Common Unit holder”) (other than us) will hold a number of XERC Common Units equal to the number of our issued and outstanding Class B common stock. The Up-C structure was selected in order to (i) provide our Continuing Equity Owners with an option to continue to hold their economic ownership interests in our business in “pass-through” form for U.S. federal income tax purposes through their ownership of XERC Common Units and (ii) potentially allow our Continuing Equity Owners and us to benefit from certain net cash tax savings that we might realize in the future, as more fully described in the subsection titled “Certain Relationships and Related Party Transactions — Tax Receivable Agreement.”
Our Market Opportunity
Load growth is accelerating globally with the International Energy Agency (the “IEA”) estimating electricity consumption to grow by more than 25% from approximately 30,000 TWh in 2023 to approximately 37,000 TWh by 2030. In the U.S., power demand is being driven by the increasing data center buildout from cloud computing providers, industrial growth and reshoring of manufacturing, and broader electrification (e.g., electric vehicle installed base). Policymakers and industry leaders recognize that nuclear, particularly advanced nuclear, will be a key contributor to meeting this load growth and securing America’s energy independence, with the stated goal of the current federal administration to expand U.S. nuclear capacity to 400 GWe by 2050 (from approximately 97 GWe at present).
We believe the market for SMRs is vast and that X-energy is well positioned to capture this opportunity. According to a 2024 report from PA Consulting, the U.S., the U.K. and Canada, X-energy’s planned core markets, comprise approximately one-third of potentially serviceable global electricity usage. Across these three geographies, there is an estimated total addressable market (“TAM”) of cumulative capacity additions of 743 GWe and 1,146 GWe by 2040 and 2050, respectively. Of this TAM, PA Consulting estimates 72 GWe in 2040 and 158 GWe in 2050 will be best served by SMRs based on needs, siting efficiencies, and demand for co-generation. These capacity additions, across a representative set of SMR use cases including powering data centers, utility power generation, industrial applications and behind-the-meter (“BTM”) generation, implies a potential need for approximately around 1,975 Xe-100 reactors (the equivalent of 494 four-reactor deployments), or an estimated $2.3 trillion market opportunity for X-energy in 2050.
We believe the following secular movements will continue to support the use cases and power needs for scalable, firm, clean baseload power that SMRs, particularly the Xe-100, can deliver.
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Demand for AI is Prompting Investment in Nuclear Power Generation. Cloud computing providers and AI companies are deploying capital across data center infrastructure to keep up with the growing computing demand required by AI. As part of this expansion, electricity demand in the U.S. from data centers is expected to grow from approximately 108 TWh in 2020 to approximately 426 TWh by 2030. Since data center facilities must be continuously powered, nuclear generation can provide a key solution for reliable supply. SMRs are particularly well suited to meet the average 300 MW to 1,000 MW power
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capacity that data centers require. SMRs have a smaller physical footprint to meet siting requirements, and have modular scalability which provides the flexibility to meet facility-specific capacity needs.
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High Carbon-Intensity Industrials Require Replacement for Industrial Heat and Steam Production. Industrial companies have historically relied on fossil fuel fired boilers to generate electricity and steam for their industrial processes. The current installed base of industrial boilers operates below capacity and is frequently offline for maintenance. The current fleet is facing a near-term replacement cycle due to age. For industrial processes requiring consistent steam availability, X-energy’s HTGR solution can reliably provide industrial steam in addition to onsite power. With an expected capacity factor of 95%, X-energy’s SMR presents a compelling replacement opportunity for aging infrastructure to both decarbonize and achieve greater reliability.
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Current Alternatives Are Not Well-Suited to Deliver Reliable, Uninterrupted, Clean and Co-Located Power.
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Renewables with or without energy storage — Solar and wind generation have relatively low-capacity factors (i.e., the actual energy output in a given period of time relative to its theoretical maximum output) of 23% and 33% (EIA) respectively, since they only produce power when the sun is shining or the wind is blowing. Addressing this inherent intermittency issue would require the integration of large-scale battery energy storage systems or supplementary dispatchable generators for the production capacity of these renewables to even be comparable with the anticipated 95% capacity factor of our reactor. Large-scale deployment of battery storage is complicated by global supply chain availability and incremental cost.
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Conventional fossil fuel generation with or without carbon capture — Standalone fossil fuel fired generation can deliver capacity factors similar to those of nuclear power but often require backup generation when maintenance takes key assets offline. Conversely, the Xe-100 can deliver critical redundancy due to its modular nature which results in a reliability advantage without requiring grid redundancy. Further, many consumers and governments have climate targets, giving SMRs (with virtually no direct GHG emissions from energy generation) a distinct advantage over carbon-intensive alternatives such as coal, oil, and natural gas generation, which would require pairing them with expensive carbon capture solutions to try to meet climate targets.
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Traditional Nuclear Power — Large-scale nuclear, while typically operating around-the-clock (other than planned outage maintenance and refueling cycles, as compared to the Xe-100’s online refueling), requires a large footprint and has consistently suffered from historical project delays and cost overruns. By contrast, advanced nuclear requires a much smaller operating footprint, on average about 1/4th to 1/10th that of a traditional nuclear plant. Additionally, HTGR sites in the U.S. will require a significantly smaller safety zone radius (400 meters versus 16 kilometers) because of built-in passive safety features. These safety characteristics enable lower costs and more compact designs due to a reduction in the quantity of concrete and steel safety infrastructure. The smaller overall footprint of SMRs allows co-location with new power demand hubs, and the modular nature of the Xe-100 enables scalable power output through additional on-site reactors to match specific needs.
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Ongoing Support from the U.S. Government Beyond the ARDP. Support for nuclear power has been increasing over the past decade with billions of additional dollars being allocated to nuclear energy through recent energy-related legislation. For instance, the One Big Beautiful Bill Act (“OBBBA”), signed in July 2025, maintained tax credits that were first introduced as part of the Energy Policy Act of 2005 and later expanded under the Inflation Reduction Act for nuclear projects. Additionally, the U.S. President issued four Executive Orders in May 2025, including support for the acceleration of regulatory review for advanced nuclear reactors and promotion of investment in a domestic nuclear supply chain. We believe these broader initiatives, building from U.S. nuclear policy precedent, will provide long-term support for advanced nuclear reactors like the Xe-100.
Competitive Strengths
As pioneers of next generation nuclear reactor and fuel technologies, we believe that our collective expertise can allow us to capitalize on our competitive strengths. We believe we will establish a leadership
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position in the evolving market, including by leveraging the strengths of our early customer relationships to give us a differentiated path to success.
Existing Customer Base Provides Initial Momentum and Support. Both Dow and Amazon have supported our initial projects, and we expect will serve as offtake customers in the future. These initial projects also enable X-energy’s goal of scaling its design to two different offtake customer applications: Industrial Heat Applications and Data Center Projects. Dow and Amazon also provide project development insight through their own operations portfolios. X-energy expects to learn from and engage with these and other customers as it builds the pipeline. This repeatable project schedule, which is also anticipated for the recently announced Centrica partnership, is expected to enable X-energy to scale from First-of-a-Kind to an Nth-of-a-Kind model that we believe will reduce our project cost and significantly derisk future projects.
Differentiated Design that Provides Attractive Solution for Customers. The characteristics of the Xe-100 provide several advantages over many other energy production alternatives. First, traditional renewables like wind and solar cannot provide reliable baseload power without being paired with longer-term storage technologies. They are also dependent on exogenous factors, which make them incapable of quickly ramping up to address increases in demand. Second, the Xe-100 has a versatile design that can be applied to several end markets, including industrial heat and conventional power generation. In addition, other emerging SMR technologies, many of which are based on conventional light water reactor (“LWR”) technology, may not be designed to efficiently load-follow or operate at temperatures high enough to provide industrial heat, and are further constrained by the availability of large amounts of water, a constraint that the Xe-100 does not have.
Improved Proven Technology. Unlike some other advanced reactor technologies, X-energy is leveraging HTGR technology that has been previously deployed across the globe, including in the U.S. at Peach Bottom and in the U.K. at Dorset (Dragon), and building on more than 50 years of research and development by the global nuclear industry. Both of these reactors served as proof-of-concept for the HTGR technology in the U.S. and, along with other HTGRs in Europe and Asia, provide valuable experience and data that X-energy has used to improve its design, leading to a more efficient, commercially deployable technology.
Intrinsically Safer Based on Physics without Needing Active Safety Systems. Our simplified Xe-100 reactor design is not dependent upon active safety systems, which are susceptible to failure and therefore necessitate the redundancy found in a typical LWR reactor design. Our design relies on physics and intrinsic safety features, such that in the event of a total loss of power to a Xe-100 reactor, the reactor does not require any operator or computer actions, grid connections, emergency backup power or additional water to cool the reactor. The reactor has a strong negative temperature coefficient, which means that increased temperature (such as from the loss of coolant circulation) slows the fission reaction, causing the reactor to shut down. Finally, due to the relatively low power density of the core, the remaining heat load is naturally dissipated through passive cooling.
Superior Fuel Based on Decades of Research & Development. We expect our TRISO-X fuel to demonstrate technical quality and a streamlined fuel qualification pathway, providing us a competitive edge in the commercial fabrication of TRISO fuel forms. The TRISO-X fuel used in the Xe-100 is a containment vessel itself and designed not to melt, enabling the technological and safety advantages of the HTGR. Due to decades of research, development and testing, including the DOE’s Advanced Gas Reactor (AGR) Fuel Development and Qualification Program, the TRISO-X particle fuel is relatively well understood. This historical data has established the parameters for TRISO-X fuel testing and qualification. Our TRISO-X pebble fuel qualification methodology is approved by the NRC, and we have a streamlined path towards final fuel qualification by the time of our first Xe-100 deployment.
Attractive Intellectual Property-Driven Business Model. X-energy serves as both a reactor technology provider and a fuel fabrication provider, offering customers an integrated solution. In our reactor business line, we expect to receive technology fees for licensing use of our proprietary Xe-100 technology, while also receiving fees for coordinating assembly and construction support with customers and anticipated blue-chip third-party vendors. We also intend to leverage our knowledge and expertise in regulatory licensing, construction, procurement, operations, maintenance and other processes to provide customers with a full suite of services from the development of a project, and ultimately for the operating life of the reactors. We do not construct the power plants and do not plan to own or operate the power plants once constructed and, as a result, do not incur capital expenditures relating to constructing, maintaining, owning or operating the
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facilities. However, we intend to remain involved with the EPC process throughout the project by providing strategic consulting related to the integration of the reactor technology. We believe this intellectual property-driven business model will position us to generate attractive free cash flow.
Leading TRISO Fuel Provider. From our TRISO-X fuel manufacturing facilities in Oak Ridge, Tennessee, X-energy plans to provide customers with initial reactor fuel loads of as well as ongoing delivery of TRISO-X fuel required to refuel plants over the lifetime of a plant. This provision of fuel to our customers would generate a strong, recurring, revenue stream. X-energy’s fuel can also be fabricated for other advanced reactor technologies, making it a key enabler of the broader advancement of the SMR space. X-energy was selected to receive one of the first allocations of HALEU from the DOE. This HALEU is required to begin initial fuel production but X-energy does not, and does not intend to, bear any significant inventory risk associated with uranium or fuel feedstock. We intend to provide only fabrication supply services for customers and assume limited risks associated with holding the title to uranium or enriched uranium fuel feedstock.
Visionary Management Team and Highly Expert Employee Base. We have an experienced and passionate team of leaders and innovators who have been directly involved in the development of advanced nuclear technology and who have led large-scale nuclear projects and operations. As of January 1, 2026, we have a highly educated workforce of 889 employees, of whom 312 have master’s degrees and 107 have Ph.Ds. Our executive leadership team has experience in nuclear design, nuclear project delivery, nuclear fuel fabrication, operations, government relations and public companies in organizations such as OPG, Hitachi-GE Nuclear Energy, Ltd. (“GEH”), the DOE, the Nuclear Regulatory Commission, Constellation Energy, Hunt Consolidated, BWXT, Westinghouse, Hartree Partners, and Emirates Nuclear Energy Corporation. The management team is led by our CEO, J. Clay Sell, who is one of the foremost leaders in the U.S. energy market. As the former Deputy Secretary of the DOE, he brings the perspective of the U.S. energy industry to X-energy. Further, his experience in renewables development after his time as Deputy Secretary has given him key experience in major project development and valuable insight into the limitations of intermittent renewable technologies, and in turn the value of nuclear generation.
Strength of Government Relationships. The ARDP significantly derisks the delivery of X-energy’s First-of-a-Kind reactor deployments through the Dow Project. Because of the 50/50 cost share program, X-energy has had significant ongoing engagement with the DOE and benefits from the DOE’s collective knowledge and support. Further, X-energy has developed high credibility with the Nuclear Regulatory Commission through our ongoing engagement for both our FOAK Fuel Fabrication facility and Dow projects, evidenced by the docketing of the first Construction Permit Application for an 18-month review schedule, one of the shortest CPA timelines ever given.
Our Business Model
We have an intellectual property-driven business model based on our reactor and fuel. We expect to derive revenues from technology licensing, services and fuel operations that span the development and operation of the reactors.
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Reactors: The revenue stream from reactors includes technology fees for the use of our intellectual property of the Xe-100 technology. We will not own and operate the facilities themselves, which we believe significantly reduces the amount of capital needed to operate our business.
We anticipate offering site-specific engineering and site characterization, project planning, assembly coordination, construction support, regulatory support, procurement support and long-term services to customers. Utilizing our knowledge and expertise in licensing, construction, procurement and other processes, we plan to provide customers with a full suite of value-added services during development of the nuclear power facilities. At the same time, we expect to generate long-term recurring revenue from services such as the ongoing maintenance and operator training through the anticipated 60-year life of a facility.
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Fuel: We intend to provide manufacturing services to customers, including producing an initial fuel load of both TRISO-X fuel and an LEU-based TRISO fuel at commissioning of a plant. We expect to generate additional long-term recurring revenue from our own proprietary TRISO-X fuel that is required to refuel plants during the anticipated 60-year life of each facility. Leveraging dedicated fuel fabrication facilities and a vertically integrated business model, we expect to be a low-cost provider of
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TRISO-X fuel, supporting customer retention and competitiveness. We expect to bear limited inventory risks related to uranium or enriched uranium fuel feedstock. We intend to provide only fabrication supply services for customers and assume limited risks associated with holding the uranium or enriched uranium fuel feedstock. Additionally, we will not have any responsibility for spent fuel management beyond the design of such facilities to adequately handle spent fuel during the life of the plant. During operations, spent fuel remains the responsibility of the plant operator. Thereafter, permanent spent fuel management remains the responsibility of the DOE.
Growth Strategies
We intend to grow our business by leveraging the competitive advantages of our differentiated and reliable Xe-100 technology and our strong customer and government relationships to achieve scale. We believe we have several avenues to achieve our growth objectives:
Continue to Develop our Next Generation Technology. We intend to continue developing our reactor and fuel technology with the goal of achieving commercial delivery of our first fleets of reactors by the early 2030s. We have substantially advanced detailed design for the Xe-100 and are working with our engineering and construction partners to complete that process. Furthermore, we will work with our initial Xe-100 customers to complete the site-specific environmental studies required for licensing and progress toward the submission of the construction permit application, including the preliminary safety analysis report. We have produced TRISO-X pebble fuel in kilogram batch quantities in our fuel fabrication pilot facility and have begun construction on North America’s first purpose-built commercial advanced nuclear fuel fabrication facility in Oak Ridge, Tennessee.
Execute on Attractive Business Development Pipeline. We believe the market for our Xe-100 and TRISO-X fuel technologies is wherever non-intermittent, reliable power is needed. We are initially focused on deploying our advanced SMRs to both industrial (including large-scale chemical manufacturing) and cloud-based service provider customers (e.g. data centers) who have needs for both electric power and efficient production of high-temperature steam with high reliability needs. We also plan to serve traditional utilities and independent power producers (“IPPs”) seeking to replace carbon-intensive fossil-fueled power plants in their jurisdictions.
Leverage Repeated Project Execution Learnings to Scale From FOAK to NOAK. Traditional nuclear has been plagued by cost and schedule overruns. Vogtle units 3 & 4 cost more than $16 .0 billion each and were seven years over schedule in part because they were the first and second AP1000 reactors deployed in the U.S. While the fourth unit was reportedly approximately 20% less expensive than the third as learnings were applied, achieving expected Nth-of-a-Kind scale with standard costs and schedule timelines is possible only through repeated project delivery over a large order book. The DOE and industry experts expect that Nth-of-a-Kind delivery can unlock potential savings of more than 30%. Starting with Dow and Amazon, X-energy is already working to deliver eight reactors across its first announced sites at Seadrift, Texas and Richland, Washington, respectively. With substantial potential for further targeted pipeline with Amazon and Centrica, we expect to be able to achieve reductions in costs and the acceleration of schedule timelines as we deliver more reactors in the future. We believe that NOAK will be achieved through repetitive project execution and financial de-risking, including early supply chain engagement, construction timeline compression, and regulatory streamlining. As we apply lessons learned from each deployment, we expect these steps will significantly reduce overall project execution costs and risks for subsequent Xe-100 projects.
Continue Geographic Expansion. Our initial core markets are the U.S., Canada and the U.K., which have sophisticated regulators that are capable of licensing our technology. Beyond these initial geographies, which together represent only one-third of the serviceable energy consumption, we anticipate expansion into new markets where we already have customer engagement, including countries in Eastern Europe, the Middle East and East Asia.
Drive Technology Advancements. Using our innovative technology platform, we believe that we are well-positioned to continue making technology advancements over time. These improvements include optimizing the Xe-100 for industrial heat applications and innovations in the design to support steam outlet temperatures greater than 800° C to support more efficient hydrogen production processes.
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Develop New Products. We continue to explore the development of innovative new products based on our core technology and varied use cases for our proprietary Xe-100 reactor, TRISO-X fuel and other microreactor technologies. TRISO-X is currently performing fuel fabrication work for others whose reactor technologies also use TRISO-based fuel, including space applications. Similarly, our Emerging Technologies team is involved in U.S. government-funded studies (such as those from the DOD) for innovative remote powering and lunar applications that may involve our microreactor and related technologies.
Our Technology
X-energy was founded by Kam Ghaffarian. The technology used today was matured through the Pebble Bed Modular Reactor program, a South African public-private partnership which advanced high temperature gas-cooled reactor technology. X-energy initially focused on the conceptual design of the Xe-100, discussed below, with an emphasis on top-level requirements designed to meet the broadest set of use cases. The company has continued to mature the Xe-100 design and has expanded into the production of TRISO fuel. Finally, X-energy has developed the design for the XENITH microreactor and we continue to invest in other research and development efforts.
Xe-100 — Our High-Performing Reactor
The Xe-100 is an HTGR which is designed to have advantages in economics, reliability and safety over conventional LWRs and other advanced SMR designs. The Xe-100 is a Generation IV advanced nuclear technology that has been designed to remedy weaknesses associated with traditional LWR designs. The Xe-100 can efficiently produce electricity or process heat. When configured for electricity generation, each reactor can power an 80 MW turbine generator. Deployment of these reactors is scalable and is optimized in a four-reactor configuration to form a 320 MWe power plant.
The Xe-100 has made substantial licensing progress. After several years of pre-application engagement, we supported Dow’s subsidiary, Long Mott Energy, LLC in submitting a construction permit application to NRC for the proposed advanced nuclear project that will use our Xe-100 reactor design in Seadrift, Texas. Citing the completeness and quality of the application, and the effectiveness of pre-application engagements, the NRC published an 18-month review timeline for the Dow project and will concurrently proceed with its environmental assessment.
![[MISSING IMAGE: ph_schematic-4clr.jpg]](https://cdn.kscope.io/66e241b40ec9a8be53aefe262681fd00-ph_schematic-4clr.jpg)
Note: Figure is intended to represent an illustrative rendering and is for illustrative purposes only.
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The Xe-100 has the following characteristics:
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Cleaner and more reliable — Like all nuclear reactors, HTGRs produce virtually zero direct GHG emissions during energy generation, are “always” on (at 95%+ availability), and provide firm, dispatchable power that is cleaner than most available firm alternatives.
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Designed with Intrinsic Safety Features — The Xe-100 HTGR is safer by design and because of the intrinsic physics of the reactor, requires fewer mechanical safety systems than traditional nuclear as well as fewer personnel for operations.
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More Secure — The TRISO-X pebble fuel is a containment vessel in itself, supporting the secure nature of the Xe-100.
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Scalable — The Xe-100 is expected to be commonly deployed in its optimized four-reactor configuration of 320 MWe, referred to as the “Xe-100 plant,” with the opportunity to scale on site to additional reactors as needed.
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Streamlined — Due to its superior intrinsic safety attributes, the Xe-100 design needs fewer safety-related specialized materials and therefore utilizes substantially more off-the-shelf components than traditional nuclear reactors, allowing for scalability from commercial vendors.
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Versatile — In addition to electricity, the Xe-100 plant can be configured to deliver high temperature steam at 565°C, providing a solution for difficult-to-decarbonize industrial heat applications such as oil sands operations, mining, chemical production and petroleum refining and other industrial processes.
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Load-following — The Xe-100 is designed to ramp down from full power to 40% power in 12 minutes and ramp back up to full power in the same short time span.
TRISO-X Pebble Fuel — Our Proprietary TRISO Fuel
Our reactors use TRISO particle fuel, a technology first developed in conjunction with the U.K.’s Dragon reactor in the 1960s. The DOE describes TRISO particles as “the most robust nuclear fuel on Earth.” We manufacture our own TRISO fuel using proprietary methods, through our wholly owned subsidiary, TRISO-X, LLC, to ensure supply and quality control. Further, many of the advanced nuclear reactor designs in development are expected to be powered by TRISO fuel or other coated-particle fuels. As part of our business model, we intend to not only sell TRISO-X fuel to our customers but to also fabricate and sell TRISO-X fuel and other encapsulated fuels to other advanced nuclear reactor customers, including governmental and private entities.
Safe, established fuel form: While TRISO fuel is already an established fuel after decades of research and development, we expect our proprietary fabrication method to further differentiate our TRISO-X fuel and deliver a competitive edge in the commercial fabrication of TRISO fuel forms. We anticipate our patented and novel process will demonstrate superior quality characteristics as well as economic performance compared to historical TRISO and potential future TRISO competitors. The TRISO-X pebble fuel is a containment vessel in itself, encased in graphite, pyrolytic carbon and silicon carbide and designed not to melt due to its ability to withstand extreme temperatures. After HALEU has been encased in a TRISO pebble form, security and proliferation risks are substantially reduced. Its robust nature allows for passive safety and, we expect a small emergency planning zone for our reactors, providing additional flexibility in site design and access to non-traditional nuclear markets and customers.
Robust integrity: Our TRISO-X pebble fuel is designed not to melt due to its robust construction. This structure minimizes the requirement for the extensive use of expensive and large concrete and steel containment structures typically required in conventional reactors.
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![[MISSING IMAGE: ph_trisoxfuel-4clr.jpg]](https://cdn.kscope.io/66e241b40ec9a8be53aefe262681fd00-ph_trisoxfuel-4clr.jpg)
Integrated fuel fabrication business: We currently manufacture TRISO-X fuel in our TRISO-X Pilot Facility in Oak Ridge, Tennessee, which has operated since 2016, and have submitted a license application to the NRC for the operation of TX-1. TX-1 will be a state-of-the-art Category II nuclear facility designed specifically for handling and processing HALEU.
Path to qualification due to extensive R&D: The ability to leverage decades of prior TRISO research and development, particularly the DOE’s Advanced Gas Reactor (AGR) Fuel Development Program, provides X-energy with a well-defined pathway for fuel qualification. X-energy’s TRISO-X Pebble Fuel Qualification Methodology has been approved by the NRC and references the AGR test results as a basis for qualification. This established framework provides X-energy a streamlined path towards obtaining qualified TRISO-X fuel by the time of its first Xe-100 deployment. Based on the approved fuel qualification methodology, we are currently in the irradiation test phase and in the final stages of qualifying our TRISO-X pebble fuel.
Long-term revenues derisked: We plan to provide our Xe-100 customers with their initial fuel loads while generating additional long-term and recurring revenue streams by refueling Xe-100 reactors throughout their anticipated 60-plus year lives. We further assume that we will be the initial sole supplier of proprietary TRISO-X fuel.
Research and Development
In addition to our core Xe-100 reactor, we continue to innovate and develop new products with our Emerging Technologies team. We are expanding our portfolio to address a broader range of energy needs and use cases beyond utility-scale power generation.
XENITH Microreactor
We have developed the XENITH microreactor, a compact solution designed to deliver reliable energy in locations where traditional power infrastructure is unavailable, impractical or vulnerable. XENITH is designed to be deployed in months and operate continuously for 20 years, delivering 3-10 MW of electricity with minimal maintenance requirements.
XENITH is not yet operational but is currently exploring commercialization opportunities. The development of the microreactor began in the Pele program through the U.S. Department of Defense (“Project Pele”), for which X-energy was awarded approximately $60 million in various contracts. Conceptual design
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was progressed during Pele Phase 1 and 2, and design work has continued into what is now the XENITH microreactor. The microreactor is likely to be deployed in a 5 MWe format, or as dual reactors in a 10 MWe electric format.
Like the Xe-100, XENITH is also a High Temperature Gas-cooled reactor that runs on TRISO fuel. The required fuel is expected to be in the form of compacts rather than pebbles. The expected operating temperature is 750 degrees Celsius. The value proposition is expected to be as follows:
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Scalable Power. Factory-built, transportable nuclear energy solution that prioritizes rapid site readiness and compatibility with existing infrastructure to support deployment in a wide range of locations.
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Resilient & Reliable. Provides reliable, long-term power with no required refueling over the 20-year lifetime, eliminating vulnerability to supply chain disruptions while providing 24/7 reliability.
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Tailored to the Target Market. Military, defense, and remote applications, including potential for black-starts, and remote communities that require secure, independent power.
Space Applications
Our innovative HTGR design and high-temperature-resistant fuel make a unique and compelling combination for nuclear electric propulsion, nuclear thermal propulsion and lunar surface power.
Our use of robust TRISO fuel in combination with innovative reactor designs and advanced moderator materials, all work together to increase the efficiency of the fission reaction while minimizing bulk and weight, keeping the reactor light enough for spaceflight. These characteristics have allowed us to develop viable concepts for a Fission Surface Power (FSP) reactor. This concept was studied through a joint venture award from the DOE and the U.S. National Aeronautics and Space Administration (NASA) in June 2022 to advance the design of a Fission Surface Power (FSP) solution.
Our Customers
Dow
Dow is X-energy’s first customer to receive a reactor and is a global leader in the specialty chemicals industry, involved in the manufacturing and distribution of a wide range of chemical and plastic products. In the course of its annual operations, Dow produces over 12 million MWh of electricity and is committed to the ongoing decarbonization of its operations.
X-energy has partnered through a Master Project Development Agreement (“MPDA”) and Commercial Cooperation Agreement (“CCA”) with Dow to provide our services in support of a FOAK deployment of four Xe-100 reactors to provide power with virtually zero direct GHG emissions and industrial steam at Dow’s UCC Seadrift site in Texas. With the support and assistance of X-energy, Long Mott Energy, LLC, a wholly owned subsidiary of Dow, filed a Construction Permit Application (“CPA”) with the NRC in March 2025 which was docketed in May 2025 for an 18-month review period with an expected review completion by late 2026 and receipt of the CPA expected in the first quarter of 2027. Initial construction can commence after receipt of the CPA.
Dow provides expertise in plant design and industrial heat as well as in the development of the Xe-100’s first plant, which will be a first-of-its-kind co-generation facility with unique heat capabilities not available in other technologies. Under the CCA, as between the parties, X-energy will own the intellectual property related to the reactor systems, controls, software, and related nuclear plant technologies, as well as fuel technology-related intellectual property, created by the parties for this project. As between the parties, Dow will own all of the conventional island intellectual property related to the non-nuclear systems that turn reactor steam into electricity and run steam and water for the facility, as well as intellectual property for equipment and processes that sit outside both the nuclear and conventional plant areas, created by the parties for this project.
Amazon
After an extensive evaluation of potential carbon free generation solutions for its extensive data center footprint, Amazon made an equity investment in X-energy in 2024 and announced options to bring more than
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5 GWe of new Xe-100 projects online across the U.S. by 2039, which assuming full exercise of these options, will represent the largest commercial deployment target of SMRs to date as of August 2025.
The first deployment under this 5 GWe total potential target is a project with Energy Northwest in central Washington. Amazon and Energy Northwest entered into a Carbon Free Development and Funding Agreement for an initial deployment of four reactors representing 320 MWe, with the potential to upsize the power capacity to 960 MWe.
Centrica
Centrica is a major provider of energy services across the U.K. and owns a 20% stake in the full fleet of operating nuclear reactors in the country. In September 2025, X-energy and Centrica signed a Joint Development Agreement (“JDA”) dedicated to building and operating Xe-100 reactors in the U.K. The announcement followed a pledge from President Donald Trump and Prime Minister Keir Starmer to work together on nuclear power and constitutes a new strategic commercial alliance to accelerate the deployment of SMRs, bringing together a leading player in delivering the U.K.’s clean energy future and the developer of the world’s most advanced nuclear technology.
The Xe-100 was selected after a significant review period by Centrica of advanced Gen IV nuclear technologies. Centrica prioritized partnership with X-energy because of the reactor’s safety and capabilities for industrial heat that Centrica sees as key to expansion in the U.K. market. The U.K. government is currently pursuing a “three-legged” approach to nuclear development, designed to ensure a diverse and resilient nuclear energy sector. Under this strategy, the first “leg” focuses on large-scale nuclear projects, such as those being developed in partnership with EDF, to provide substantial baseload power. The second “leg” supports the deployment of Gen III+ light water SMRs, with Rolls Royce’s SMR technology selected as the leading solution in this category. The third “leg” is dedicated to other small and advanced modular reactors, including HTGRs like Xe-100, which are prioritized for their potential to deliver both electricity and high-grade industrial heat, supporting decarbonization across a range of sectors.
X-energy and Centrica have identified Hartlepool as the preferred site for the first of a planned U.K. fleet of approximately six GWe (representative of 76 reactors likely deployed as 19 four-reactor configurations). A project at Hartlepool will be comprised of up to twelve 80 MWe reactors, each with the capability to provide high temperature steam for industrial decarbonization Subject to securing appropriate permissions and licenses, the first electricity generation is expected to be in the mid-2030s.
Other Key Partnerships
Department of Energy
Through the ARDP, we are partnering with DOE and others to build the world’s first commercial scale advanced nuclear reactor. In December 2020, X-energy, initially in collaboration with Energy Northwest, was selected for a project, initially in the amount of $1.2 billion, to deliver a first-of-a-kind commercial advanced nuclear plant and TRISO-X fuel fabrication facility. This project is now being developed with Dow with continued financial support from the DOE on a 50/50 cost share basis. As one of only two parties selected out of many applicants, X-energy was recognized as having an advanced reactor technology of choice.
Ontario Power Generation
In 2022, X-energy and OPG entered into a framework agreement to work exclusively with one another with respect to advanced nuclear power industrial applications in Ontario, Canada, and to co-market and advance the Xe-100 as the nuclear technology of choice for industrial applications throughout Canada. OPG will be the operator of any Xe-100 facilities that are deployed under this agreement. OPG is also an equity investor in X-energy.
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Our Key Supply Chain Partners
We have a network of partners that enable our growth and success. These partners include:
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Curtiss-Wright. Curtiss-Wright is a leading U.S. designer and supplier of critical nuclear power plant systems, equipment, services, and spare parts to the U.S. domestic and global nuclear power industry. Following several competitive bid processes, X-energy selected Curtiss-Wright as the successful bidder for multiple Xe-100 systems. Curtiss-Wright was selected as a preferred strategic supplier to X-energy for the ARDP and subsequent Xe-100 projects in the U.S. Curtiss-Wright is an equity investor in X-energy.
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Doosan Enerbility (“Doosan”). Doosan is a preferred strategic supplier to X-energy. Doosan is a major global manufacturer and supplier of core components of nuclear power plants, such as reactor pressure vessels, steam generators, and steam turbines. Doosan has a vertically integrated manufacturing facility in Changwon, Korea, which is capable of raw material production to final assembly of nuclear components. Doosan has manufactured and supplied 34 reactor pressure vessels and 124 steam generators globally. Doosan is an equity investor in X-energy. In December 2025, Doosan signed a Reservation Agreement with X-energy, committing to the construction of a new SMR fabrication facility to support the execution of X-energy’s more than 11 GWe commercial pipeline.
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DL E&C. DL E&C will work with X-energy to identify opportunities around the world to employ best practices to support the development and deployment of Xe-100 plants on a global scale. Founded in 1939, DL E&C has the longest business history among construction companies in Korea and has maintained a top ten Korean engineering and construction company ranking for the past 50+ years. DL E&C is the flagship company of DL Group, and has a broad range of experience in global mid/downstream energy sector engineering, procurement and construction, providing total services and solutions in more than 35 nations, focusing on a more sustainable and better future. DL E&C is an equity investor in X-energy.
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Korea Hydro & Nuclear Power (“KHNP”). KHNP is the Korean entity that operates its nuclear and hydroelectric sector as a subsidiary of Korea Electric Power Corporation (“KEPCO”), the majority state-owned utility. Since 1971, KHNP has successfully constructed and operated 30 nuclear power plants still in operation today, 26 in South Korea and four in the United Arab Emirates (“UAE”). KHNP provides significant expertise in the construction of nuclear reactors. In August 2025, KHNP signed a joint compact with X-energy, Amazon, and Doosan outlining the intention to collaborate on the deployment of the Amazon order book in the U.S.
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SGL Carbon LLC (“SGL”). SGL is a developer and manufacturer of advanced carbon materials. X-energy and SGL have collaborated since 2015 on the qualification of NBG-18 graphite for use in the Xe-100, leveraging SGL’s experience manufacturing graphite for high-temperature gas-cooled reactors. In January 2026, SGL announced a 10-year graphite supply agreement for reactor components of X-energy’s Xe-100 SMRs, and has commenced production for the Dow Seadrift plant site as part of an initial three-year award valued at over $100 million.
SUMMARY RISK FACTORS
Investing in our common stock involves substantial risk. The risks described under the section titled “Risk Factors” immediately following this prospectus summary may cause us to not realize the full benefits of our objectives or may cause us to be unable to successfully execute all or part of our strategy. Some of the more significant challenges include the following:
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We have not yet delivered a commercial Xe-100 or achieved final investment decisions (FIDs) for any deployments; our FOAK schedule, cost, and performance are uncertain and delays or setbacks, particularly on initial projects, could materially harm our business, reputation, and finances.
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We may not generate sufficient liquidity to fund operations and growth; our business is capital intensive and we will require substantial additional financing, which may not be available on acceptable terms and could be dilutive.
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Our business depends heavily on U.S. government support, including the ARDP; future appropriations are uncertain, and any reduction, delay, or termination, or failure to obtain needed increases due to inflation and cost growth, could materially and adversely affect our projects, TX-1 fuel facility plans, and commercialization.
•
We face significant regulatory and licensing risks for both our reactors and fuel facilities; NRC and other regulatory approvals may be delayed, conditioned, or denied, including as a result of public interventions and hearings, which could increase costs and extend timelines.
•
Access to HALEU is limited and failure of commercial HALEU supply to materialize on required timelines and at predictable costs could delay fuel fabrication (TX-1 and beyond) and reactor deployments and impair competitiveness.
•
Our cost, schedule, and unit economics are subject to substantial uncertainty, including inflation, supply chain constraints, labor availability, site-specific factors, and first-of-a-kind risks; if cost reductions from NOAK learning are lower or slower than expected, our products may not be cost competitive.
•
We have limited operating and commercial experience at our intended scale and configuration; latent design, manufacturing, construction, or operational issues may emerge late and be costly to remediate.
•
We rely on a limited number of specialized suppliers (including graphite and other nuclear-grade materials and first-of-a-kind components); supply disruptions, quality issues, shipping/logistics risks, tariffs, or trade policy changes could delay projects and increase costs.
•
Safety, security, and cybersecurity incidents at our facilities, our customers’ facilities, or elsewhere in the nuclear industry, could result in regulatory actions, project delays, increased costs, reputational harm, and reduced demand.
•
Market adoption of Gen IV SMRs is nascent and uncertain; demand may grow more slowly than expected, customers may defer or cancel projects, and our products may face competition from low-cost alternatives (including gas, renewables with storage, or other advanced reactors).
•
We face intense competition from domestic and state-supported international nuclear suppliers; competitors may have greater resources, faster regulatory paths in some jurisdictions, or lower costs, which could pressure pricing and margins.
•
Our reliance on key partners and customers, including Dow (ARDP) and cloud computing providers, exposes us to counterparty and execution risk; changes in partner priorities, funding, or timelines could materially affect our path to commercialization. Our JDA with Centrica is non-binding and may not result in definitive agreements or revenues.
•
Customer contractual terms (including Amazon’s priority queue slots, rights of first refusal, and most favored pricing) may constrain capacity allocation, compress margins, increase operational complexity, and expose us to payment or performance obligations.
•
Our fuel business depends on licensing and scaling TX-1 and subsequent facilities; delays in NRC licensing, materials qualification, or facility construction, or inability to recruit and retain specialized talent, could impair fuel availability and recurring revenue.
•
We may not carry insurance covering performance of the Xe-100 or all relevant project risks; even if obtained, insurance may be unavailable, insufficient, or costly.
•
Changes in laws, regulations, incentives, export controls, or government policies could increase costs, delay approvals, limit market access, restrict technology transfers, or reduce the value of expected incentives.
•
Public perception and political support for nuclear energy can shift; adverse events, activism, or changes in policy priorities could slow licensing and deployment and increase costs.
•
Spent fuel and governmental waste management policies remain unsettled; customer concerns about storage or disposal costs and responsibilities could reduce demand for our technology.
•
We depend on key personnel and our ability to hire and retain highly specialized talent; shortages, immigration constraints, or turnover could delay programs and increase costs.
13
•
We have identified material weaknesses in internal control over financial reporting; failure to remediate existing weaknesses or to maintain effective controls could adversely affect our financial reporting and the market price of our stock.
•
We are subject to intellectual property risks; we may be unable to obtain, maintain, or enforce intellectual property rights, or we may face third-party claims that could require costly litigation, licensing, redesigns, or limit commercialization; our IP protection is territorial and may be limited abroad.
•
Data privacy and cybersecurity risks could lead to service interruptions, regulatory inquiries, liability, and reputational harm; increased AI use introduces additional privacy, IP, bias, and compliance risks.
•
We are exposed to construction, siting, industrial application, severe weather, disaster, and logistics risks; catastrophic events or unusual siting requirements could increase costs, delay schedules, and strain resources.
•
Our illustrative capacity figures and unit economics in this prospectus are estimates based on numerous assumptions (including technology fees, services, and fuel pricing); actual results may differ materially, including lower pre- and post-COD revenues and margins.
•
Compliance with government contracting requirements (FAR, False Claims, pricing/cost rules) and audits carries risk of penalties, repayment, suspension, or debarment; U.S. budget deficits, shutdowns, and continuing resolutions may disrupt program funding and payments.
•
Export/import controls and sanctions can restrict sales, technology transfers, and collaborations; violations or policy shifts could result in penalties and lost market access.
•
Energy market rules and oversight (including FERC, NERC, and ISO/RTO market design) may affect customer project economics and indirectly our demand; noncompliance could result in sanctions on customers.
•
Tax law changes and interpretations (including OBBBA) may increase complexity, audit risk, and effective tax rates; changes in accounting estimates and quarterly variability could materially impact reported results.
•
As a holding company, we will depend on distributions from our operating subsidiary to fund taxes, expenses (including under a Tax Receivable Agreement), and any dividends; such distributions may be restricted, and TRA payments (including upon change of control or early termination) may be substantial and could exceed realized tax benefits, constraining liquidity.
•
An active trading market for our Class A common stock may not develop or be sustained; our stock price may be volatile, large sales (including post lock-up) may depress the price, analyst coverage may be limited, and you may lose part or all of your investment.
Please see “Risk Factors” for a more complete discussion of these and other risks.
IMPLICATIONS OF BEING AN EMERGING GROWTH COMPANY
We are an emerging growth company, as defined in Section 2(a) of the Securities Act, as modified by the Jumpstart Our Business Startups Act of 2012 (the “JOBS Act”), and we may take advantage of certain exemptions from various reporting requirements that are applicable to other public companies that are not emerging growth companies, including relief from the auditor attestation requirements of Section 404 of the Sarbanes-Oxley Act, less extensive disclosure obligations regarding executive compensation in our registration statements, periodic reports and proxy statements, exemptions from the requirements to hold a non-binding advisory vote on executive compensation, and exemptions from stockholder approval of any golden parachute payments not previously approved. We may also elect to take advantage of other reduced reporting requirements in future filings. As a result, our stockholders may not have access to certain information that they may deem important and the information that we provide to our stockholders may be different than, and not comparable to, information presented by other public reporting companies. We could remain an emerging growth company until the earliest of (i) the last day of the year following the fifth anniversary of the completion of this offering, (ii) the last day of the year in which we have total annual gross revenue of at least $1.235 billion, (iii) the last day of the year in which we are deemed to be a “large accelerated filer” as defined
14
in Rule 12b-2 under the Exchange Act, which would occur if the market value of our Class A common stock and Class B common stock held by non-affiliates exceeded $700.0 million as of the last business day of the second fiscal quarter of such year and (iv) the date on which we have issued more than $1.0 billion in non-convertible debt securities during the prior three-year period.
In addition, the JOBS Act also provides that an emerging growth company may take advantage of the extended transition period provided in the Securities Act for complying with new or revised accounting standards. An emerging growth company may therefore delay the adoption of certain accounting standards until those standards would otherwise apply to private companies. We have elected to avail ourselves of this exemption and, as a result, will not be subject to the same implementation timing for new or revised accounting standards as are required of other public companies that are not emerging growth companies, which may make comparison of our financial information to those of other public companies more difficult.
CORPORATE INFORMATION
X-Energy Reactor Company, LLC is a Delaware limited liability company formed on December 14, 2018, and is the predecessor for financial reporting purposes of X-Energy, Inc., a Delaware corporation formed on September 18, 2025.
X-energy’s principal executive offices are located at 530 Gaither Road, Suite 700, Rockville, MD 20850 and our phone number is (301) 358-5600.
Our website address is www.x-energy.com. Information contained in, or accessible through, our website is not a part of this prospectus, and the inclusion of our website address in this prospectus is only an inactive textual reference.
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ORGANIZATIONAL STRUCTURE
In connection with the closing of this offering, we will undertake certain organizational transactions subsequent to which we will conduct our business through what is commonly referred to as an “Up-C” structure, which is often used by partnerships and limited liability companies when they decide to undertake an initial public offering. Unless otherwise stated or the context otherwise requires, all information in this prospectus reflects the consummation of the Reorganization Transactions.
Following the consummation of the Reorganization Transactions (as more fully described under “Organizational Structure”), we will be a holding company. Our sole material asset will be our equity interest in XERC, which, through its direct and indirect subsidiaries, conducts all of our operations. Because X-energy, Inc. will be the sole managing member of XERC, we will indirectly operate and control all of the business and affairs (and will consolidate the financial results) of XERC its subsidiaries.
Prior to the consummation of the Transactions, the capital structure of XERC consists of three classes of membership interests: Common Units, Preferred Units and Incentive Units.
In connection with the consummation of this offering, we will complete a series of reorganization transactions, including: (i) the eighth amendment and restatement of the XERC LLC Agreement to, among other things, effect a recapitalization in which all existing ownership interests in XERC are converted into one class of Common Units; (ii) the amendment and restatement of the X-energy, Inc.. certificate of formation to, among other things, authorize two classes of common stock; (iii) X-energy, Inc.’s designation as managing member of XERC, (iv) X-energy, Inc.’s acquisition of common units held by the Blocker Companies pursuant to the Blocker Mergers, (v) X-energy, Inc.’s acquisition of common units held by the Blocker Companies pursuant to the Blocker Mergers, (vi) X-energy Inc’s acquisition of common units held by certain of the Continuing Equity Owners in exchange for an equal number of shares of Class A common stock and (vii) X-energy, Inc.’s issuance of Class B common stock to the Continuing Equity Owners in exchange for a nominal cash contribution made by such Continuing Equity Owners, resulting in a combined company organized in Up-C structure. See “Organizational Structure” and “Certain Relationships and Related Party Transactions” for additional information.
Prior to the completion of the offering, X-energy, Inc. and XERC will enter into a Tax Receivable Agreement with the TRA Holders. This Tax Receivable Agreement will provide for the payment by X-energy, Inc. to the TRA Holders of 85% of the benefits, if any, that X-energy, Inc. is deemed to realize (calculated using certain assumptions) as a result of the Basis Adjustments and Interest Deductions. Assuming no material changes in the relevant tax laws and that we earn sufficient taxable income to realize all tax benefits that are subject to the Tax Receivable Agreement, we expect the tax savings associated with the purchase of Common Units in connection with this offering, together with future redemptions or exchanges of all remaining Common Units owned by the TRA Holders pursuant to the XERC LLC Agreement as described above, would aggregate to approximately $ million over years from the date of this offering based on the assumed initial public offering price of $ per share of our Class A common stock (the midpoint of the estimated price range set forth on the cover page of this prospectus), and assuming all redemptions or exchanges would occur immediately after the initial public offering for the remaining ownership of XERC not acquired by X-energy, Inc. Under such scenario, assuming future payments are made on the date each relevant tax return is due, without extensions, we would be required to pay approximately 85% of such amount, or approximately $ million over the -year period from the date of this offering, to the TRA Holders. The actual amounts we will be required to pay under the Tax Receivable Agreement may be significantly different from the amounts described in the preceding sentence. See “Risk Factors — Risks Related to Our Capital Structure” and “Certain Relationships and Related Party Transactions — Tax Receivable Agreement” for additional information regarding the Tax Receivable Agreement.
16
The following diagram reflects our simplified organizational structure after giving effect to the Transactions, including this offering:
![[MISSING IMAGE: fc_public-bwlr.jpg]](https://cdn.kscope.io/66e241b40ec9a8be53aefe262681fd00-fc_public-bwlr.jpg)
We intend to use all of the net proceeds we receive from this offering to purchase newly issued Common Units from XERC. In the event the underwriters exercise their option to purchase additional shares of Class A common stock, we intend to use any proceeds from such exercise to purchase additional newly issued Common Units from XERC. See “Organizational Structure,” “Use of Proceeds,” and “Certain Relationships and Related Party Transactions”.
Subject to the terms and conditions of the XERC LLC Agreement, the Continuing Equity Owners will have the right to have XERC redeem their Common Units for shares of Class A common stock on a one-for-one basis or, at our election (determined solely by our independent directors (within the meaning of Nasdaq rules) who are disinterested), a corresponding amount of cash, in either case, contributed to XERC by X-Energy, Inc., unless X-Energy, Inc. elects, in its sole discretion (determined solely by our independent directors (within the meaning of Nasdaq rules) who are disinterested), to effect such transaction as a direct exchange with the relevant Continuing Equity Owner. Upon any such redemption or exchange of Common Units, the corresponding shares of Class B common stock held by such Continuing Equity Owner will be surrendered and immediately canceled. See “Certain Relationships and Related Party Transactions — XERC LLC Agreement” for additional information regarding such redemption and exchange rights.
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THE OFFERING
Common stock offered by us
shares of Class A common stock.
Common stock offered by the selling stockholders
shares (including shares to be issued upon exercise of options by certain selling stockholders in connection with the sale of such shares in this offering).
Class A common stock to be outstanding after this
offering
offering
shares (including shares to be issued upon exercise of options by certain selling stockholders in connection with the sale of such shares in this offering), or shares if the underwriters exercise their option to purchase additional shares of Class A common stock in full.
Class B common stock to be outstanding after this
offering
offering
shares (including shares to be issued upon exercise of options by certain selling stockholders in connection with the sale of such shares in this offering), or shares if the underwriters exercise their option to purchase additional shares of Class A common stock in full.
Common Units to be outstanding after this offering
Common Units, representing an approximately % economic interest in XERC (or Common Units, representing an approximately % economic interest in XERC, if the underwriters exercise their option to purchase additional shares of Class A common stock in full).
Option to purchase additional shares
The underwriters have an option to purchase up to an aggregate of additional shares of common stock from us and additional shares of common stock from the selling stockholders identified in this prospectus. The underwriters can exercise this option at any time within 30 days from the date of this prospectus.
Use of proceeds
We estimate that the net proceeds to us from the sale of shares of our common stock in this offering will be approximately $ million.
We intend to use the proceeds from this offering to acquire newly issued Common Units from XERC. The foregoing purchases of Common Units will be at a price per unit equal to the public offering price per share of Class A common stock in this offering, less the underwriting discounts and commissions. XERC intends to use the proceeds received from us for working capital and other general corporate purposes, which may include research and development and sales and marketing activities, general and administrative matters, and capital expenditures. We may also use a portion of the proceeds for future growth projects. See “Use of Proceeds.” We will not receive any proceeds from the sale of shares of common stock by the selling stockholders.
Voting rights
Holders of shares of our Class A common stock and our Class B common stock will vote together as a single class on all matters presented to shareholders for their vote or approval, except as otherwise required by law or our amended and restated certificate of formation.
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Each share of our Class A common stock and Class B common stock entitles its holder to one vote on all matters to be voted on by shareholders generally. See “Description of Capital Stock.”
Redemption rights for Common Units
Prior to this offering, we will amend and restate the XERC LLC Agreement so that the Continuing Equity Owners may (subject to the terms of such limited liability company agreement), elect to have XERC redeem their Common Units for either shares of Class A common stock on a one-for-one basis or at our election (determined solely by our independent directors (within the meaning of Nasdaq rules) who are disinterested), a corresponding amount of cash, in either case, contributed to XERC by X-Energy, Inc., unless X-Energy, Inc. elects, in its sole discretion (determined solely by our independent directors (within the meaning of Nasdaq rules) who are disinterested), to effect such transaction as a direct exchange with the relevant Continuing Equity Owner. Upon any such redemption or exchange of LLC Units, the corresponding shares of Class B common stock will be canceled. See “Certain Relationships and Related Party Transactions — XERC LLC Agreement.”
Dividend policy
We do not expect to pay any dividends on our common stock for the foreseeable future. See “Dividend Policy.” The declaration, amount and payment of any future dividends will be at the sole discretion of our Board. Our Board may take into account general economic and business conditions, our financial condition and operating results, our available cash and current and anticipated cash needs, capital requirements, contractual, legal, tax, and regulatory restrictions, and implications on the payment of dividends by us to our shareholders or by our subsidiaries (including XERC) to us, and such other factors as our Board may deem relevant. Holders of our Class B common stock do not have any economic rights or any right to receive dividends (except for certain in-kind dividends), or to receive a distribution upon a liquidation, dissolution, or winding up of X-Energy, Inc., with respect to their Class B common stock.
X-Energy, Inc. is a holding company and has no material assets other than a controlling equity interest in XERC. The XERC LLC Agreement that will be in effect at the time of this offering provides that certain distributions to cover the taxes of the holders of Common Units will be made based upon assumed tax rates and other assumptions provided in such limited liability company agreement. Additionally, in the event X-Energy, Inc. declares any cash dividend, we intend to cause XERC to make distributions to X-Energy, Inc., in an amount sufficient to cover such cash dividends declared by us. If XERC makes such distributions to X-Energy, Inc., the other holders of Common Units will also be entitled to receive the respective equivalent pro rata distributions in accordance with their respective ownership of vested Common Units.
Tax Receivable Agreement
Upon the completion of this offering, we will be a party to the Tax Receivable Agreement with XERC and the TRA Parties. Under the Tax Receivable Agreement, we generally will be required to pay to the TRA Parties 85% of the amount of tax benefits, if any, that we actually realize (or in some circumstances are deemed to realize) as a result of (i) Basis Adjustments and (ii) payments made under the Tax Receivable Agreement. We will retain the benefit of the remaining 15% of these tax benefits. See “Organizational Structure.”
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Stock exchange symbol
“XE”
Risk factors
Investing in our common stock involves a high degree of risk. See “Risk Factors” beginning on page 23 in this prospectus for a discussion of factors you should carefully consider before investing in our common stock.
Except as otherwise indicated, the number of shares of our Class A common stock and Class B common stock to be outstanding immediately after this offering is based on an aggregate of shares of Class A common stock and Class B common stock (which includes shares of common stock and shares of unvested restricted common stock subject to a repurchase option by us) outstanding as of , and excludes:
•
shares of Class A common stock reserved for issuance upon redemption or exchange of Common Units that will be held by the Continuing Equity Owners on a one-for-one basis; and
•
shares of Class A common stock reserved for future issuance under our 2026 Incentive Award Plan (the “2026 Plan”), which will become effective upon the effectiveness of the registration statement of which this prospectus forms a part (which number includes shares of our Class A common stock subject to restricted stock unit awards and stock options that will be granted to certain of our employees and directors pursuant to our 2026 Plan substantially concurrently with the consummation of this offering, based upon an assumed initial public offering price of $ per share (the midpoint of the estimated price range set forth on the cover page of this prospectus)).
•
In addition, our 2026 Plan provides for annual automatic increases in the number of shares reserved thereunder.
Unless otherwise indicated, this prospectus assumes or gives effect to:
•
the completion of the Transactions described under “Organizational Structure,” including the amendment and restatement of the XERC LLC Agreement and the reclassification of all outstanding equity of X-Energy Reactor Company, LLC into a single class of Common Units, which will occur immediately prior the closing of this offering (the Recapitalization);
•
no exercise of outstanding stock options referred to above;
•
no exercise by the underwriters of their over-allotment option;
•
an assumed initial public offering price of $ per share, which is the midpoint of the estimated price range set forth on the cover page of this prospectus; and
•
the filing and effectiveness of our amended and restated certificate of incorporation and the effectiveness of our amended and restated bylaws, each of which will occur immediately prior to the completion of this offering.
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SUMMARY HISTORICAL AND PRO FORMA FINANCIAL INFORMATION OF X-ENERGY
The following table shows summary historical and pro forma financial data for each of the periods indicated. The summary historical financial information for X-energy presented below for the years ended December 31, 2024 and 2023 have been derived from X-energy’s audited financial statements included elsewhere in this prospectus. The unaudited summary pro forma consolidated financial data set forth below as of and for the nine months ended September 30, 2025 and for the year ended December 31, 2024 have been derived from our unaudited pro forma condensed consolidated financial statements included elsewhere in this prospectus.
The unaudited pro forma condensed statement of operations for the year ended December 31, 2024 and the nine months ended September 30, 2025 gives effect to the pro forma events as if they had been consummated on January 1, 2024, the beginning of the earliest period presented. The unaudited pro forma condensed balance sheet as of September 30, 2025 gives effect to the pro forma events as if they had been consummated on September 30, 2025. We have derived the unaudited pro forma condensed balance sheet and the unaudited pro forma condensed statements of operations from our unaudited condensed consolidated financial statements as of and for the nine months ended September 30, 2025 and our audited consolidated financial statements for the year ended December 31, 2024, which are included elsewhere in this prospectus. The pro forma adjustments are based on available information and upon assumptions that management believes are reasonable in order to reflect, on a pro forma basis, the effect of the pro forma events on our historical financial information. The adjustments are described in the notes to the unaudited pro forma condensed balance sheet and the unaudited pro forma condensed statements of operations. The unaudited pro forma condensed financial information is presented for illustrative purposes only and do not purport to represent the results of operations or the financial position that would actually have occurred had the pro forma events been consummated on the dates assumed or to project the Company’s results of operations or financial position for any future date or period.
The summary information in the following tables should be read in conjunction with “Basis of Presentation — Organizational Structure,” “Capitalization,” “Management’s Discussion and Analysis of Financial Condition and Results of Operations of X-energy,” and our financial statements and accompanying notes included elsewhere in this prospectus.
|
Consolidated Statements of Operations
|
| |
Nine months
ended September 30, 2025 |
| |
Year ended
December 31, 2024 |
| |
Year ended
December 31, 2023 |
| |
Pro Forma
Nine Months ended September 30, 2025 |
| |
Pro Forma
Year Ended December 31, 2024 |
| |||||||||||||||
|
Services revenue
|
| | | $ | 60,411 | | | | | $ | 83,986 | | | | | $ | 121,877 | | | | | $ | | | | | $ | | | ||
|
Grant income
|
| | | | 12,324 | | | | | | 36,166 | | | | | | 11,165 | | | | | | | | | | | | | | |
|
Total revenues and grant income
|
| | | | 72,735 | | | | | $ | 120,152 | | | | | $ | 133,042 | | | | | | | | | | | | | | |
| Operating expenses: | | | | | | | | | | | | | | | | | | | | | | | | | | | |||||
|
Direct costs
|
| | | | 103,679 | | | | | | 130,115 | | | | | | 199,586 | | | | | | | | | | | | | | |
|
Selling, general and administrative
|
| | | | 77,451 | | | | | | 111,887 | | | | | | 68,693 | | | | | | | | | | | | | | |
|
Research and development
|
| | | | 1,376 | | | | | | 1,662 | | | | | | 2,150 | | | | | | | | | | | | | | |
|
Total operating expenses
|
| | | | 182,506 | | | | | | 243,664 | | | | | | 270,429 | | | | | | | | | | | | | | |
|
Operating loss
|
| | | | (109,771) | | | | | | (123,512) | | | | | | (137,387) | | | | | | | | | | | | | | |
| Other income (expense): | | | | | | | | | | | | | | | | | | | | | | | | | | | |||||
|
Interest expense
|
| | | | (476) | | | | | | (16,190) | | | | | | (8,262) | | | | | | | | | | | | | | |
|
Interest income
|
| | | | 14,824 | | | | | | 2,833 | | | | | | 178 | | | | | | | | | | | | | | |
|
Other income (expense), net
|
| | | | (222,655) | | | | | | 10,909 | | | | | | (85,749) | | | | | | | | | | | | | | |
|
Total other expense, net
|
| | | | (208,307) | | | | | | (2,448) | | | | | | (93,833) | | | | | | | | | | | | | | |
|
Net loss
|
| | | | (318,078) | | | | | | (125,960) | | | | | | (231,220) | | | | | | | | | | | | | | |
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|
Balance Sheet Data
|
| |
As of
September 30, 2025 |
| |
As of
December 31, 2024 |
| |
As of
December 31, 2023 |
| |
Pro Forma as of
September 30, 2025 |
| |||||||||
|
Total assets
|
| | | $ | 561,699 | | | | | $ | 579,510 | | | | | $ | 75,571 | | | | | |
|
Total liabilities
|
| | | | 328,788 | | | | | | 125,695 | | | | | | 274,686 | | | | | |
|
Total mezzanine equity
|
| | | | 1,388,492 | | | | | | 1,300,376 | | | | | | 516,775 | | | | | |
|
Total members’ deficit
|
| | | | (1,155,581) | | | | | | (846,561) | | | | | | (715,890) | | | | | |
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RISK FACTORS
Investing in our Class A common stock involves a high degree of risk. You should consider carefully the risks and uncertainties described below, together with all of the other information in this prospectus, including the section titled “Management’s Discussion and Analysis of Financial Condition and Results of Operations of X-energy” and our consolidated financial statements and the accompanying notes included elsewhere in this prospectus before deciding whether to invest in shares of our Class A common stock. The risks and uncertainties described below are not the only ones we face. Additional risks and uncertainties that we are unaware of or that we deem immaterial may also become important factors that adversely affect our business. If any of the following risks occur, our business, financial condition, operating results, and future prospects could be materially and adversely affected. In that event, the market price of our Class A common stock could decline, and you could lose part or all of your investment.
Throughout this section, unless otherwise noted, the “Company,” “we,” “us” or “our” refers to X-Energy, Inc. and its consolidated subsidiaries.
Risks Relating to X-energy’s Business
Our ability to execute on our business plan and our continued existence are dependent upon our ability to obtain additional funding and financing.
While we currently expect that we have sufficient sources of liquidity, taking into account our current cash on hand and the expected net proceeds from this offering, to continue working on our reactor and fuel projects with our key customers and partners, we will need additional sources of funding and financing to support our ongoing operations and to execute on our business plan.
We have had, and expect that we will continue to have, an ongoing need to raise additional capital from outside sources to fund our operations and expand our business. Historically, our primary sources of funding to support our operations have been revenue from the ARDP contract, contributions and loans from members, loans from financial institutions and capital raises.
As of September 30, 2025, we had cash and cash equivalents of $426.8 million and continue to meet our obligations to customers, vendors, counterparties and employees in the ordinary course of business. Our expected primary uses of cash on a short-term and long-term basis are for working capital requirements, capital expenditures, and other general corporate services. Our primary working capital requirements are for project execution activities including purchases of materials, subcontracted services and payroll which fluctuate during the year, driven primarily by the timing and extent of activities required on new and existing projects. We expect that working capital requirements will need to continue to be funded through a combination of cash on hand, funding awarded under the ARDP contract, further issuances of securities, and capital raises.
In addition, management expects that future operating losses and negative operating cash flows may increase from historical levels because of additional costs and expenses related to the development of our technology and the development of market and strategic relationships with other businesses. In particular, in connection with our business plan, management anticipates additional increases in operating expenses and capital expenditures relating to the development and commercialization of the Xe-100. We intend to finance these expenses with further issuances of debt or equity securities. Thereafter, we expect we will need to raise additional capital and generate revenues to meet long-term operating requirements.
If we raise additional funds through the issuance of equity or convertible debt securities, the percentage ownership of our equity holders could be significantly diluted, and these newly issued securities may have rights, preferences or privileges senior to those of existing equity holders. If we raise additional funds by obtaining loans from third parties, the terms of those financing arrangements may include negative covenants or other restrictions on our business that could impair our operating flexibility and also require us to incur interest expense.
If we are unable to raise additional capital when desired, we may not be able to construct the TX-1, deliver the Xe-100 or any other reactor to customers on time or on budget or at all, conduct other research and
23
development, undertake other projects, or fulfill our business plan, and therefore, we may need to delay or abandon these and other projects.
Any of the foregoing would materially and adversely affect our business, financial condition, operating results, and future prospects.
We may not generate sufficient revenues or liquidity to operate our business, and a successful transition to attaining profitable operations depends upon achieving a level of revenue adequate to support us.
We expect that working capital requirements will need to continue to be funded through a combination of cash on hand, funding awarded under the ARDP contract, further issuances of securities, and capital raises. In addition, we will need to generate increased revenues sufficient to meet long-term operating requirements.
At present, our revenues are generally derived from contract services performed for the U.S. government and commercial entities from cost-share agreements such as the ARDP and research and development, product development, and fuel services provided to other government agencies and commercial entities. In the future, we expect to generate revenue through licensing or technology fees for the use of the proprietary intellectual property and build-to-print design of the Xe-100 technology, project planning, assembly coordination, construction support, regulatory support, procurement support, long-term services to customers and the supply of fuel and associated services. However, we have not yet entered into any such licensing, technology or other agreements, and there can be no assurances that customers will accept our anticipated fees and pricing under these agreements or that we will be able to charge the fees and pricing that we anticipate under our business plan. If we are unable to obtain sufficient fees and pricing under these agreements, our business, financial condition, operating results and future prospects will be materially and adversely affected.
Our revenue growth also may be adversely affected by other factors including: our inability to maintain, grow and develop the X-energy products; our ability to continue to receive funding from government contracts; weakness in the industry generally; general economic conditions, including as a result of tariffs, high interest rates and inflation; terrorism, sanctions or other geopolitical events globally; global pandemics and other public health emergencies; increasing competition; and the other risks described in this “Risk Factors” section.
Our historical revenue growth is not indicative of our future performance. If we are unable to maintain, grow, and develop X-energy’s business and generate sufficient revenue and achieve profitability, our business, financial condition, operating results and future prospects will be materially and adversely affected. We may also achieve business growth in quantity of deployed plants, but achieve lower than anticipated revenue on each deployment, including achieving lower than anticipated margin on our projects. Additionally, our cash needs may increase in the future as we focus on growing and developing products.
Our future capital requirements will depend on many factors, including the ability to meet (or continue to meet, as the case may be) the requirements of Nasdaq for listing or any other exchange, future credit losses, the ability to obtain the necessary financing to meet obligations and repay liabilities arising from business operations when they come due, the ability to generate and maintain sufficient cash, and the ability to generate profitable operations in the future. There can be no assurance that our liquidity will be sufficient to achieve our long-term objectives, grow and develop our products, operate our business, or comply with the terms of our indebtedness.
If we are not able to generate sufficient revenues or liquidity to operate our business, and to support our long-term business plan, it would materially and adversely affect our business, financial condition, operating results, and future prospects.
We have not yet delivered the Xe-100 or any other reactor to customers and have not achieved final investment decisions for the purchase or deployment of any of our reactors, and there is no guarantee that we will be able to do so. Any delays or setbacks we may experience during our first commercial delivery, which is planned for the early 2030s, or failure to obtain final investment decisions would have a material adverse effect on our business, financial condition, operating results, and future prospects, and could harm our reputation.
The success of our business will depend in large part on our ability to successfully deliver the Xe-100 to customers on time and on budget at guaranteed performance levels, which would give greater confidence in
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our subsequent customers. There is no guarantee that our planned deployments of the Xe-100 will be successful, on schedule, or on budget, or that our customers will elect to exercise their options for additional Xe-100 units. We are in the design phase of the Xe-100, and as a result our cost and schedule estimates are subject to significant uncertainty and change. Our current cost model and estimates have limited fidelity and may prove inaccurate, which could result in material cost growth, schedule extensions, or scope changes that adversely affect project economics, final investment decisions and customer commitments.
Moreover, because the Xe-100 will be considered a first-of-a-kind technology, there can be no assurance that we will not experience operational or process failures and other problems during our first commercial deployment or any planned deployment thereafter. The nuclear industry has historically experienced significant cost overruns, schedule delays and cancellations on first-of-a-kind and follow-on projects, which have, in many cases, rendered projects uneconomical; similar dynamics could affect our projects notwithstanding our planning, risk management and contracting strategies. In the event that we fail to develop and successfully commercialize our technology, if we fail to develop such first-of-a-kind technologies before our competitors or if such technologies fail to perform as expected, are inferior to those of our competitors or are perceived as less safe than those of our competitors, our business and financial condition could be materially and adversely impacted. Any failures, delays or setbacks, particularly on our first commercial deployments, would likely harm our reputation and have a material adverse effect on our business prospects, financial condition, results of operation and cash flows.
Any delays in the development and manufacture of our SMRs and related technology may adversely impact our business and financial condition.
We have previously experienced and may experience in the future, delays, cost overruns or other complications in the design, manufacture, production and delivery of the Xe-100 and related technology, such as the TRISO-X Fuel Fabrication Facility, that could prevent us from delivering any SMRs on our current anticipated timeline. For example, as part of our iterative Xe-100 reactor design process, we employ phased development cycles and review gates to progress from concept through product delivery. Each system within the reactor plant undergoes a thorough assessment at each gate to determine if all product requirements (for example, performance, safety, delivery) are being met or are at risk of not achieving full capability. In the course of certain major gate reviews of the Xe-100 reactor design in the past, we identified areas where further design or analysis work was required to achieve a fully acceptable engineered design. Likewise, development delays at our Fuel Fabrication Facility site have occurred in connection with resolving certain infrastructure requirements and environmental analyses prior to commencing construction. While the aforementioned activities, and others like them, have not materially delayed delivery for a customer to date, they may do so in the future. If delays like these occur, if our remediation or resolution measures and process changes do not continue to be successful, if we fail to find satisfactory manufacturers or suppliers, or if we experience issues with planned manufacturing or construction activities or design and safety, we could experience issues or delays in reaching, sustaining or increasing deployment and sales of our SMRs. The effect of such delays may be increased as a result of rising commodity prices and interest rates, which may increase costs to us and to our customers and may adversely affect the competitiveness of our reactors compared to more established, competing means of supplying electricity or heat.
We are highly dependent on our partnership with Dow for the successful and timely installation of the Xe-100 at our first-of-a-kind facility at one of Dow’s U.S. Gulf Coast sites under the ARDP, and any slowdown, suspension or termination of this project could have a material adverse effect on our business, financial condition, results of operations, cash flows and stock price.
Our joint development agreements with Dow, including our MPDA, provide for certain engineering services, site selection, joint NRC licensing, technology use and further the ARDP-related work that is funded by Dow and is subject to the DOE’s and Dow’s ongoing support and approval. As such, we are reliant on Dow’s continued partnership to develop and finalize the business model for the ARDP and to establish a framework to pursue industrial projects in connection therewith, including the initial deployment of the Xe-100 pursuant to the ARDP. Such framework includes critical elements for the successful deployment of our initial Xe-100, including marketing, project ownership structures, project delivery models, plant operations, incentive structures, finance arrangements and other joint responsibilities and obligations.
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Our strategic plan contemplates the Dow project serving as a cornerstone reference facility to validate our technology, execution capabilities and commercial model. There is no guarantee that this project will proceed as planned, on schedule or on budget. As a first-of-a-kind facility, it is subject to significant uncertainties, including permitting and regulatory approvals, engineering and design changes, supply chain constraints (including long-lead nuclear components and fuel), contractor performance, labor availability, site access and infrastructure, safety or environmental incidents, community opposition, financing availability, force majeure and other factors beyond our control. We also depend on Dow and other counterparties to perform their obligations; we do not control their decisions, priorities or operations. For example, Dow may terminate its MPDA and CCA with us at any time for convenience without regard for our performance. Cost growth, schedule extensions, scope changes or performance shortfalls at this facility could impair project economics, delay or prevent subsequent customer commitments and final investment decisions, and damage our reputation. If Dow were to terminate and neither Dow nor another potential near-term customer enters into similar agreements with us, our initial deployment of the Xe-100 and ongoing services associated with such deployment could be significantly delayed, and the initial deployment of the Xe-100 under the ARDP government cost-sharing arrangement could also be significantly delayed. This could adversely affect our business, financial condition, results of operations and cash flows.
Any slowdown, suspension or termination of work on the Dow facility due to technical challenges, regulatory or legal proceedings, funding constraints, counterparty defaults or termination or other disruptions could materially and adversely affect our ability to commercialize our technology, limit revenue generation, increase cash burn, require additional capital on unfavorable terms, and reduce investor confidence. Such events, particularly because of the project’s prominence and first-of-a-kind nature, could have a material adverse effect on our business prospects, financial condition, results of operations and cash flows, and could result in significant volatility in, or a decline of, our stock price.
Furthermore, we can offer no assurances as to how Dow will respond to program cost increases or schedule delays. Addressing cost overruns is part of our ongoing commercial negotiations with Dow as a customer and partner in the ARDP. The ARDP is adjusted periodically to meet the current needs of the participants in the program. Any such response, including a change in the nature of our relationship with Dow or its project timeline, funding and cost estimates, or willingness to participate as a sub-awardee under the ARDP, could result in a materially adverse outcome to our business prospects.
Our joint development agreement with Centrica is non-binding, and there can be no assurance that it will result in definitive agreements or any future revenue, which could have a material adverse effect on our business, financial condition, results of operations and cash flows.
Our JDA with Centrica to explore the potential deployment of the Xe-100 in the U.K. is non-binding. The JDA is preliminary in nature and does not obligate either party to enter into definitive agreements, commit capital, or proceed with any specific project. The continuation of discussions and any future collaboration remain subject to a number of conditions and contingencies, including, among others, negotiation and execution of binding contracts, receipt of regulatory approvals, site selection, financing arrangements, and the satisfaction of other commercial and technical requirements.
There can be no assurance that we will be able to reach agreement with Centrica on definitive terms, or that any project contemplated by the JDA will proceed. Even if definitive agreements are reached, the timing, scope, and economics of any resulting project may differ materially from our current expectations. If the relationship with Centrica does not progress as anticipated, or if Centrica elects not to move forward with the development or purchase of our reactors, we would not realize any of the potential revenues or strategic benefits associated with the arrangement. Any failure to convert the JDA into a binding commercial agreement, or any delay or cancellation of potential projects under the JDA, could adversely affect our business, financial condition, results of operations and cash flows.
Our sales and profitability may be impacted by, and we may incur liabilities as a result of, terms to certain customers, our failure to meet performance guarantees under customer contracts or customer safety standards.
Terms in contracts or agreements we have entered into with existing or future customers may constrain our capacity allocation, impact our pricing and margins, and limit our strategic flexibility. Under our agreements with Amazon, we have granted Amazon first-priority allocation of Xe-100 manufacturing queue
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slots across 2031 to 2039 to allocate to utilities and independent power producers, primarily current nuclear operators, who will ultimately own and operate the SMR facilities. We have also granted Amazon a right of first refusal on a portion of our scheduled delivery. While Amazon is not obligated to purchase, its rights could limit our ability to allocate capacity to other customers and may lead to underutilization or planning inefficiencies if Amazon delays or declines to exercise its allocated capacity. Under our agreements with Amazon, we are also obligated to offer Amazon the most favorable pricing and commercial terms available to any non-affiliate customer, including minimum TRISO-X fuel allocations commensurate with our most favored customers. If we cannot make a reserved slot available, we must use commercially reasonable efforts to provide replacement capacity to honor our targets under the agreement.
These commitments may reduce our flexibility to prioritize higher-margin or strategic customers and require us to match the best terms we offer to others, which could compress margins and adversely affect revenue mix. They may also increase operational complexity and costs (including TRISO-X fuel allocations) and result in disputes. Additionally, successor and transfer provisions require any transferee of manufacturing assets or relevant equity interests to assume queue-slot obligations, which could limit our ability to pursue strategic transactions or restructurings on favorable terms.
Under our agreements with Amazon, beginning on the fifth anniversary of the commercial operations date of the first Amazon-sponsored project, we are required to make payments to Amazon reflecting the cost efficiencies we have achieved relative to the PPA prices applicable to the initial projects. These obligations could be material, and could adversely affect our liquidity, cash flows, and financing flexibility, particularly if our costs decline on other projects, which would increase the premium owed on Amazon-sponsored projects. The timing and magnitude of payments may be volatile due to annual reforecasts, project performance, and exogenous variables, reducing cash available for operations, investment, and debt service, and potentially extending the final maturity beyond our original expectations.
Further, we anticipate that our customers may require performance guarantees as to the performance of the Xe-100s we deliver. Prospective future customers may also require that we comply with their own unique requirements relating to their compliance with policies, priorities, regulations, controls, and mandates, including provision of data and related assurance for environmental, social, and governance related standards or goals, and such compliance may add cost and timeline uncertainty or risk. Failure of our products to operate properly or to meet specifications of our customers or our failure to meet our performance guarantees may increase costs by requiring additional engineering resources and services, replacement of parts and equipment or monetary reimbursement to a customer, or could otherwise result in liability to our customers. There are significant uncertainties and judgments involved in estimating performance guarantee obligations, including changing product designs, differences in customer installation processes and failure to identify or disclaim certain variables. To the extent that we incur substantial performance guarantee claims in any period, our earnings and ability to obtain future business could be materially adversely affected.
The illustrative capacity figures and unit economics included in this prospectus are illustrative in nature, are based on a number of assumptions, and may not reflect our actual future performance.
The illustrative capacity figures presented in this prospectus are based on our current agreements with customers, including Dow, Amazon, and Centrica, and reflect our internal assumptions regarding the capacity of the Xe-100, the number of units that may be deployed, and the time periods in which we anticipate such units being constructed and placed into service. Numerous risks and uncertainties could cause the actual deployed capacity to differ materially from the illustrative figures, including our and our customers’ ability to successfully construct and deliver Xe-100s (none of which have been built or operated to date) or to do so on a timely basis, obtain required regulatory approvals, secure adequate financing, and manage supply chain constraints, labor availability, cost overruns, and construction delays. In addition, customers such as Dow, Amazon, and Centrica have rights to delay, reduce, or terminate their commitments, and any such changes, along with potential modifications in the scope, scale, or timing of customer projects, technological or engineering challenges, or shifts in energy policy, electricity market demand, or public acceptance of nuclear power, could materially impact our ability to achieve the levels of capacity reflected in this prospectus. As a result, our actual cumulative deployed capacity may be substantially less than that shown, or may not be achieved at all, and investors should not place undue reliance on these illustrative figures in evaluating our business, financial condition, operating results or future prospects.
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We do not carry insurance coverage for the risks associated with the Xe-100 or its components, and our current insurance coverage may not be adequate, or we may not be able to obtain insurance at acceptable rates at all.
We do not carry insurance coverage for the performance of the Xe-100 or its components. Even if we purchase this kind of insurance, the insurance may not fully protect us from the financial impact of defending against product liability claims that may occur in future. In the event that our technologies fail to perform as expected, are inferior to those of our competitors or are perceived as less safe than those of our competitors, our business and financial condition could be materially and adversely impacted. Other than contractual protections provided by our vendors for certain components and systems, we have not employed other risk sharing structures to mitigate all risks associated with the successful delivery and performance of the Xe-100. As we have not yet delivered the Xe-100 or any other reactor to customers, we have determined that our current insurance coverage is sufficient for our business operations. However, we may need to purchase additional insurance to operate our business. If we fail to obtain the required insurance, or if we were to incur substantial losses or liabilities due to fire, explosions, floods, other natural disasters or accidents or business interruption that we not adequately covered under our existing insurance, our business and results of operations could be materially and adversely affected.
We depend significantly on U.S. government contracts, which often are only partially funded, subject to immediate termination, and heavily regulated and audited. Continued full funding of, and any upward adjustments to funding available under, the ARDP are subject to future government appropriations and continued political support. The termination of, or failure to fully fund, the ARDP, or our failure to timely secure upward adjustments in the ARDP funding to cover actual costs could have a material, adverse impact on our business prospects, relationship with our partners, financial condition, results of operations and cash flows and may result in a more limited ARDP fuel facility development, changes to project development timelines, or other commercial changes to the ARDP.
In addition to at least $500 million funding appropriated in FY2020-FY2024, the Infrastructure Investment and Jobs Act (Public Law 11758) appropriated funds for the ARDP in total of $2.47 billion. Of ARDP funding to date, at least $1.1 billion has been allocated to X-energy’s award. Ongoing ARDP funding is provided to X-energy through ongoing Continuation Applications, with the latest funding through at least August of 2026. Congress has appropriated approximately $1.1 billion of the $1.2 billion commitment as part of the Infrastructure Investment and Jobs Act in 2022 to support our ARDP award. In recent years, U.S. government appropriations have been affected by larger U.S. government budgetary issues and related legislation. As of September 30, 2025, we have received over $394 million in funding under the ARDP. We cannot predict the extent to which funding may be increased, if at all, or if total funding may be reduced as part of a subsequent appropriations process ultimately approved by U.S. Congress and the President of the U.S. or in separate supplemental appropriations or continuing resolutions, as applicable. The termination of funding for the ARDP would result in a loss of anticipated future revenue attributable to that program, which could have an adverse impact on our operations. In addition, the termination of the ARDP or the failure to commit additional funds to the ARDP could result in lost revenue and increase our overall costs of doing business, and may result in the deferral or more limited development of TX-1 and subsequent fuel fabrication facilities, and jeopardize our ability to complete our initial deployments of the Xe-100, which could adversely affect our ability to market and deploy Xe-100 units to other customers and other commercial effects.
Generally, U.S. government contracts are subject to oversight audits by U.S. government representatives. Such audits could result in adjustments to our contract costs. Any costs found to be improperly allocated to a specific contract will not be reimbursed, and such costs already reimbursed must be refunded. We have recorded contract revenue based on costs we expect to realize upon final audit. However, we do not know the outcome of any future audits and adjustments, and we may be required to materially reduce our revenue or profits upon completion and final negotiation of audits. Negative audit findings could also result in termination of a contract, forfeiture of profits, suspension of payments, fines or suspension or debarment from U.S. government contracting or subcontracting for a period of time.
U.S. government contracts generally contain provisions permitting termination, in whole or in part, without prior notice at the U.S. government’s discretion upon payment only for work done and commitments made at the time of termination. Under some contracts, we are a subcontractor and not the prime contractor, and in those arrangements, the U.S. government could terminate the prime contractor for convenience without
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regard for our performance as a subcontractor. We can give no assurance that one or more of our U.S. government contracts will not be terminated under those circumstances. Also, we can give no assurance that we would be able to procure new contracts to offset the revenue lost as a result of any termination of our U.S. government contracts. Because a majority of our revenue is dependent on our performance and payment under our ARDP contract, the loss of that particular contract could have a material adverse impact on our business, financial condition, operating results and future prospects.
Our contracts and services with the U.S. government are also subject to specific procurement regulations and a variety of socioeconomic and other requirements. These requirements, although customary in U.S. government contracts, increase our performance and compliance costs. These costs might increase in the future, reducing our margins, which could have a material adverse effect on our business prospects, financial condition, results of operations and cash flows. The U.S. government has implemented, and may continue to implement initiatives focused on efficiencies, affordability and cost control and other changes to its procurement practices. These initiatives and changes to procurement practices may change the way U.S. government contracts are solicited, negotiated and managed, which may affect whether and how we pursue opportunities to provide our products and services to the U.S. government, including the terms and conditions under which we do so, which may have an adverse impact on our business, financial condition, operating results and future prospects.
Failure to comply with applicable regulations and requirements could lead to fines, penalties, repayments, or compensatory or treble damages, or suspension or debarment from U.S. government contracting or subcontracting for a period of time. Among the causes for debarment are violations of various laws and regulations, including those related to procurement integrity, export control (including the International Traffic in Arms Regulations at 22 C.F.R. Parts 120-130), U.S. government security, employment practices, protection of the environment, accuracy of records, proper recording of costs and foreign corruption. The termination of a U.S. government contract or relationship as a result of any of these acts would have an adverse impact on our operations and could have an adverse effect on our standing and eligibility for future U.S. government contracts.
Government funding is subject to the political process, which is inherently unpredictable, highly competitive and dependent on budgetary limitations, congressional appropriations and administrative allotment of funds, all of which may be affected by changes in U.S. government policies resulting from various political developments. If political support for the prioritization of the development of nuclear energy decreases, including due to policy changes by the current administration or future administrations and changing congressional funding priorities, we may be unable to secure continued government funding under the ARDP or any requested increases to such funding. Our failure to secure upward adjustments in the ARDP funding to cover actual costs, should such a need arise, could have a material, adverse impact on our business prospects, which would materially and adversely affect our development timeline, financial condition, relationship with our partners, results of operations and cash flows. In addition, any such failure to obtain requested increases to such funding could result in a more limited ARDP fuel facility development or other commercial changes to the ARDP.
In addition, in connection with future requests for increases to funding under the ARDP, in connection with our entry into U.S. government contracts, or for any other reason, the U.S. government may stipulate conditions or make certain requests of us in return, including, but not limited to, requests for amendments to existing U.S. government contracts or requests to acquire and/or purchase shares of our Class A common stock or securities that give the U.S. government the right to acquire shares of our Class A common stock. Any such conditions or requests, whether or not we agree to them, and the terms of any such securities, could have a material adverse impact on our relationship with the U.S. government, could have a material adverse effect on our business prospects, financial condition, results of operations and cash flows, and could result in significant volatility in, or a decline of, our stock price.
Our business plan may also include the development of other configurations of our SMR or other new projects, and makes certain assumptions with respect to learnings, efficiencies, and regulatory approvals as a result of this new development approach which may not be accurate or correct. Any adverse change to these assumptions may have a material adverse effect on our business prospects, financial condition and results of operations and cash flows.
We compete in a market characterized by rapid technological advances, evolving regulatory standards in software technology and frequent new product introductions and enhancements. To succeed, we may also rely
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on the development of other configurations of our SMRs or other new projects we may decide to undertake. The development of other configurations of our SMRs, or the undertaking of other new projects, has inherent risks, including, but not limited to:
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higher than expected research and development costs;
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delays or unexpected costs in developing new plant configurations;
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ability or delays in obtaining regulatory approval;
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customers delaying purchase decisions in anticipation of new configurations;
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customer confusion and extended evaluation and negotiation time;
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educating our sales, marketing, and consulting personnel to work with new configurations;
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competition from earlier and more established entrants;
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market acceptance of earlier configurations; and
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the accuracy of assumptions about the nature of customer demand.
If we are unable to successfully introduce, market, and sell other configurations of our SMRs, or undertake any other new projects in a timely and cost-effective manner, and properly position and/or price our products, our business, financial condition, operating results and future prospects could be materially impacted.
If we fail to manage our growth effectively, we may be unable to execute our business plan, and our business, financial condition, operating results and future prospects could be harmed.
In order to achieve the substantial future revenue growth we have projected, we must finalize our reactor design, receive regulatory approvals, including NRC licensing of our TX-1 fuel facility and subsequent fuel fabrication facilities, and continue to develop and market new products and services to traditional and nontraditional end users. We intend to expand our operations significantly to meet anticipated demand. To properly manage our growth, we will need to hire and retain additional personnel, upgrade our existing operational management and financial and reporting systems, and improve our business processes and controls. Our future expansion will be dependent on:
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hiring and training new personnel with the skill and expertise required;
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completing the licensing and construction of TX-1 and subsequent fuel fabrication facilities and optimizing the production of our TRISO-X fuel;
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finalizing our reactor design and developing new technologies and services (e.g., training, maintenance, procurement);
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optimizing applications of our reactors to serve both traditional utility and electric power customers and a broad base of nontraditional industrial customers interested in utilizing the efficient high temperature heat produced by our design;
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controlling expenses and investments in anticipation of expanded operations and rising costs;
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manufacturing and maintaining a sufficient supply of pebbles;
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managing the costs of our reactors;
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managing construction timelines, performance and budgets of our engineering, procurement and construction (“EPC”) partners and other third-party contractors;
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upgrading the existing operational management and financial reporting systems and team to comply with requirements as a public company; and
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implementing and enhancing administrative infrastructure, systems and processes.
If our operations continue to grow as planned, of which there can be no assurance, we will need to expand our sales and marketing, research and development, customer and commercial strategy, products and
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services, supply chain, and manufacturing functions, among others. These efforts will require us to invest significant financial and other resources, including in industries and sales channels in which we have limited experience to date. We will also need to continue to leverage our manufacturing and operational systems and processes, and there is no guarantee that we will be able to scale the business as currently planned or within the planned timeframe. The continued expansion of our business may also require additional manufacturing and operational facilities, as well as space for administrative support, and there is no guarantee that we will be able to find suitable locations for such facilities.
Our continued growth could increase the strain on our resources, and we could experience operating difficulties, including difficulties in hiring and training employees, finding manufacturing capacity to produce our SMRs and related equipment, delays in production, challenges in scaling up fuel and component fabrication capacity and difficulty sourcing adequate raw material, such as graphite and HALEU, for our reactors. These difficulties may divert the attention of management and key employees and impact financial and operational results. If we are unable to drive commensurate growth, these costs, which include lease commitments, headcount and capital assets, could result in decreased margins, which could have a material adverse effect on our business, financial condition, operating results and future prospects.
Further, if our capital needs are greater than anticipated or the timing of expenditures accelerates, we may need to raise additional debt or equity, reduce scope, defer projects, or pursue alternative delivery models and risk-sharing structures; there can be no assurance such capital will be available when needed or on acceptable terms. See Risks Related to X-energy’s Capital Resources — In order to fulfill our business plan, we will require additional funding. To the extent we require such additional investor funding in the future, such funding may be dilutive to our investors and no assurances can be provided as to terms of any such funding. Any such funding and the associated terms will be highly dependent upon market conditions and the progress of our business at the time we seek such funding. The terms of any financing that we pursue may be less favorable than previously anticipated and could become even less favorable depending on the amount of funds we may require.
There is limited commercial operating experience for our planned SMRs and facilities, configuration, and scale. This creates risks in cost and schedule estimates and lack of recent domestic commercial experience in terms of labor and supply chain and other factors may result in greater than expected construction cost, deployment timelines, maintenance requirements, differing power output and greater operating expense.
While our SMR design will be actively managed through design reviews, prototyping, testing, involvement of external partners with subject matter expertise, and application of approaches utilized in the operation of the Xe-100, we could still fail to identify latent design, manufacturing, construction, and operations issues early enough to avoid negative effects on production, fabrication, construction or ultimate performance of the Xe-100 and related technologies, or we may encounter unexpected regulatory issues. Moreover, the cost and time associated with the construction and maintenance of our SMRs may be greater than we or our customers expect because we or they may face a lack of a domestic labor force with relevant commercial experience and an inexperienced or insufficient supply chain for this type of reactor. Where these issues arise at later stages of deployment, deployment could be subject to greater costs or be significantly delayed, which could materially and adversely affect our business. Although nearly all of the cost to construct the Xe-100 is borne by our customers, such costs incurred by our customers could significantly exceed their and our expectations, including for reasons outside of their and our control, which could make existing or prospective customers less likely to contract with us and use our SMR design in the future, which could have a material adverse effect on our business, results of operations and financial prospects.
We have not yet entered into any technology fee agreements with our customers, which could materially impact our revenue model.
A key component of our business model generally and the illustrative unit economics provided in this prospectus is the ability to reach binding agreements with potential customers for use of and access to our Xe-100 technology and designs and to realize the fees associated with such agreements. To date, we have not entered into any such agreements with our customers, and our customers have not paid such fees, and there can be no assurance that they will enter into such agreements in the future at levels currently anticipated or at all. Potential customers may resist paying technology fees given the substantial capital expenditures already associated with the construction of SMRs, or the potential development of technologies that may prove more
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efficient or effective. If we are unable to enter into these agreements or enforce or collect these fees, our expected revenue streams could be materially reduced.
Any failure to effectively create the design, ensure its commercial viability and implement the construction and operations of our planned SMRs and facilities or ensure cost competitiveness could reduce the marketability of X-energy designs and has the potential to impact deployment schedules.
Creating our designs and ensuring their commercial viability and implementing the construction and operations will be necessary to be competitive and attractive in the market, particularly in the U.S. where the price of power is generally lower than in certain other key markets. If we are not able to achieve and maintain cost competitiveness of our fuel or our planned SMRs in the U.S. or elsewhere, our business could be materially and adversely affected.
We may not attract customers to our Xe-100 technology as quickly as we expect, or at all, and acquiring customers may be more expensive than we currently anticipate.
Adoption of the Xe-100 among our potential customers may progress more slowly than we anticipate or it may be more expensive to bring potential customers into our pipeline. Any delay or failure to attract potential customers to our reactors or SMR technology may have a material and adverse impact on our business and financial condition.
The amount of time and funding needed to bring our nuclear fuel to market at scale may significantly exceed our expectations. Any material change to our assumptions or expectations, or any material overruns or other unexpected increases in costs, could have a material adverse effect on our expected revenues, gross margins and on the other information included in the illustrative unit economics provided in this prospectus or our ability to develop and market other coated particle fuels.
The development of our TRISO-X fuel at scale will take a significant amount of time and funding. TRISO-X fuel is produced through a highly specialized, small-batch manufacturing process. Scaling from pilot-scale production to commercial-scale production involves significant technical, regulatory, and economic challenges. Any shortfall in research, development, and testing funds, unexpected or significant increases in costs, any delay in achieving fuel development milestones, and any uncertainty in regulatory licensing timelines or adverse public reaction to developments in the use of nuclear power by special interest groups, community organizations and state and local government agencies leading to environmental litigation or other legal proceedings could result in significant delays and cost overruns and could adversely affect our ability to deploy, and our customers’ ability to operate, the Xe-100. At this stage, we cannot accurately predict the amount of funding or the time required to successfully manufacture and sell our nuclear fuel in the future at scale. The actual cost and time required to commercialize our fuel technology may vary significantly from our initial forecasts depending on, among other things:
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the results of our research and product development efforts;
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the cost of developing or licensing our nuclear fuel and TX-1 and any subsequent fuel facilities;
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the cost to construct and operate TX-1 and subsequent fuel fabrication facilities, including potential construction delays;
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the ability of customers to efficiently adopt and use TRISO-X fuel in their reactors;
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changes in the focus and direction of our research and product development programs;
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access to test facilities;
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competitive and technological advances;
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the cost of filing, prosecuting, defending, and enforcing claims with respect to patents;
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the regulatory approval process;
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the fuel manufacturing process;
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adverse public reaction to the developments in the use of nuclear power resulting in environmental litigation or other legal proceedings;
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staffing and training qualified personnel to operate TX-1 and any other TRISO-X fuel facilities;
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the scalability of our TRISO-X fuel operations;
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availability and cost of LEU and HALEU;
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availability and cost of other raw materials necessary for fuel manufacturing, including graphite, process gases, and chemicals, among others; and
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marketing and other costs associated with commercialization of these technologies.
Because of this uncertainty, even if financing is available to us, we may need significantly more capital than anticipated, which may not be available on terms acceptable to us or at all. As a result, the expected revenues and other expected benefits from our nuclear fuel technology may be delayed or never realized. Any material change to our assumptions or expectations, or any material overruns or other unexpected increase in costs, could have a material adverse effect on our expected revenues, gross margins and on the other information included in the illustrative unit economics provided in this prospectus or our potential to develop and market other coated particle fuels.
If our customers are unable to access HALEU, our ability to manufacture TRISO-X fuel will be adversely affected, which could have a material adverse effect on our business, financial condition, operating results and future prospects.
Existing commercial nuclear infrastructure, including enrichment facilities and fuel fabrication facilities, were in most cases designed and are currently licensed to handle uranium in pellet and rod form, with enrichment up to 5% of the isotope Uranium 235 (LEU). Our fuel designs are based on a spherical pebble design composed of graphite, pyrolytic carbon and silicon carbide encapsulated uranium particles that have been enriched up to 15.5% for use in the Xe-100. This higher enriched uranium (greater than 5% but still below 20%) is known as HALEU. Supplying HALEU to our TX-1 and any subsequent fuel fabrication facilities, which will manufacture the fuel for our SMRs, will require certain modifications to NRC licensing of existing commercial uranium enrichment facilities, none of which are owned or operated by us, along with the construction and NRC licensing of our TX-1 and any subsequent fuel fabrication facilities.
Presently, HALEU enrichment services are available only in limited quantities globally. In the U.S., HALEU can be sourced in limited quantities from the DOE, and a limited domestic supply from the private sector that we do not expect will be a significant source of our HALEU. Despite U.S. government initiatives designed to ensure initial HALEU quantities, including the establishment of the HALEU Availability Program to ensure access to HALEU for civilian domestic research, development, demonstration, and commercial use, the HALEU program is still in its early stages, and significant progress is required to achieve reliable and scalable production.
Government funding is subject to the political process, which is inherently unpredictable and can be highly competitive. The funding of government programs is dependent on budgetary limitations, congressional appropriations and administrative allotment of funds, all of which may be affected by changes in U.S. government policies resulting from various political developments, including recent efforts to negotiate an increase in, or suspension of, the debt ceiling. If an alternative commercial-scale supply of HALEU outside of Russia or China fails to materialize, including as a result of a lack of political support for the prioritization of the development of nuclear energy or otherwise, it may affect our ability to secure HALEU fuel in the future, which would materially adversely affect our business, financial condition, operating results and future prospects.
Our initial ARDP plant deployment may consequently depend on HALEU feedstocks released by the U.S. government, which may initially be in the form of highly enriched uranium, or “HEU” (enriched above 20%), that will be down-blended to HALEU levels for use in our TX-1, any subsequent fuel fabrication facilities and, ultimately, in ARDP reactors owned and operated by our partners. HEU can be processed to HALEU by only a limited number of licensed U.S. third parties. These third parties do not currently produce commercial levels of HALEU and may require regulatory approvals and process changes in order to produce the HALEU we require for the ARDP plants. Our customers’ longer term fuel feedstock supply arrangements and subsequent fuel fabrication, whether related to X-energy’s TRISO-X fuel or other coated particle fuels we
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may manufacture for others, are likely to rely on commercial suppliers that do not yet produce and market HALEU, and which will also require NRC regulatory licenses in order to do so. Therefore, our customers’ ability to obtain adequate long term HALEU supplies for our reactors on a predictable schedule and at predictable cost may be impaired, and activities like fuel loading, testing, and ultimate operation of our SMRs may be delayed, and our customers exposed to cost and schedule uncertainty, all of which may negatively affect the competitiveness of our SMRs.
Any HALEU enrichment facility will need to secure NRC licenses to enrich uranium to HALEU levels, and our TX-1 and any subsequent fuel fabrication facilities will require an NRC license to accept and fabricate HALEU into TRISO-X fuel. There is risk of relevant entities within the nuclear power industry being slow to make any required facility infrastructure modifications or to obtain and maintain required licenses or approvals to enable such enrichment of HALEU fuel. Finally, there is a risk associated with possible negative public perception of uranium enrichment to greater than 5% that could potentially delay or hinder regulatory approval of our nuclear fuel designs. Should any of these events occur, our business would be materially adversely impacted.
Unsatisfactory safety performance or security incidents at our facilities, or any nuclear facility around the world, could have a material adverse effect on our business, financial condition, operating results and future prospects.
We design and will facilitate the manufacturing of highly sophisticated SMRs that depend on complex technology. We also work cooperatively with our suppliers, subcontractors, venture partners and other parties. Failures, disruptions or compromises to our or our third parties’ systems or facilities may be caused by natural disasters, accidents, power disruptions, telecommunications failures, acts of terrorism or war, computer viruses, bugs or vulnerabilities, physical or electronic break-ins, human error, targeted cyberattacks, other intentional conduct, or similar events or incidents. While we have built operational processes to ensure that the design, manufacture, performance and servicing of our SMRs meet rigorous safety standards and performance goals, there can be no assurance that we will not experience operational or process failures or other problems, including through manufacturing or design defects, failure of third-party safeguards, mishandling or process failures, natural disasters, cyber attacks, or other intentional acts, that could result in potential safety risks. There can be no assurance that our preparations, or those of third parties, will be able to prevent or address any such incidents.
Any actual or perceived safety issues at our facilities, those of our customers, or any nuclear facility around the world may result in significant reputational harm to our businesses; in addition, such safety issues at our or our customers’ facilities could result in enforcement proceedings brought by government regulators, tort liability, maintenance costs, increased safety infrastructure requirements and other costs that may arise. Such issues with our SMRs, facilities, or customer safety could result in delaying or cancelling delivery of SMRs to our customers, increased regulation or other systemic consequences. Our inability to meet our safety standards or address adverse publicity affecting our reputation as a result of accidents, mechanical failures, damages to customer property or medical complications could have a material adverse effect on our business, financial condition and results of operation.
In the nuclear industry, an accident or incident involving the mishandling of nuclear materials at any nuclear facility in the world can have an impact on other nuclear facilities around the world in terms of public acceptance, political pressures, and regulatory requirements and scrutiny. For example, the March 2011 accident at the Fukushima Daiichi plant in Japan resulted in millions of dollars in additional regulatory reviews and requirements for U.S. nuclear power plants. As a result of the Fukushima accident, some countries that were considering launching new domestic nuclear power programs delayed or cancelled the preparatory activities they were planning to undertake as part of such programs. If a safety incident occurs at any nuclear facility in the world, it could delay licensing and/or drive up costs to license or own our SMRs and negatively impact our business or financial condition.
We rely on a limited number of suppliers for certain materials and supplied components, some of which are highly specialized and are being designed for first-of-a-kind or sole use in the Xe-100. We and our third-party vendors may not be able to obtain sufficient materials or supplied components to meet our manufacturing and operating needs, or obtain such materials on favorable terms or at expected costs.
We rely on a limited number of suppliers for certain raw materials and supplied components. We may not be able to obtain sufficient raw materials or supplied components to meet our manufacturing and operating
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needs, or obtain such materials on favorable terms or at expected costs, which could impair our ability to fulfill our orders in a timely manner or increase our costs of production.
We do not directly manufacture any of the components of our SMRs. Our ability to manufacture our SMRs is dependent upon sufficient availability of raw materials and supplied components, including many highly technical components that are still under design, are being designed for first-of-a-kind or sole use in the Xe-100 and have not yet been qualified for use, are only produced by a limited number of suppliers and may be particularly susceptible to cost increases, supply chain disruptions or inflationary pressures. Any supply chain disruption incurred by our third party suppliers or degradation in the quality and processes of our manufacturer partners, may result in delays, cost overruns or impairments to the development of our reactors.
Certain materials, such as the graphite used to line our reactor cores and for our TRISO-X fuel and helium, which is used as a reactor coolant, are currently produced in limited quantities and currently available from a limited number of vendors, which in some cases are predominantly outside of the U.S. (e.g., Germany and Japan). There is also increasing scrutiny on the environmental, social, or geographic provenance of certain goods, including critical minerals, which may require us to incur certain costs or further limit our ability to source certain goods required for our operations. For example, in December 2021, the U.S. adopted the Uyghur Forced Labor Prevention Act (“UFLPA”) which creates a rebuttable presumption that any goods, wares, articles, and merchandise mined, produced, or manufactured in whole or in part in the Xinjiang Uyghur Administrative Region of China or that are produced by certain entities are prohibited from importation into the United States. These import restrictions came into effect on June 21, 2022. While we are not presently aware of any direct impacts of these restrictions on our supply chain, the UFLPA may have an adverse effect on global supply chains which could adversely impact our business and results of operations. Although U.S. graphite suppliers are developing the capability and capacity to supply our needs, our current reliance on foreign suppliers to secure raw materials and supplied components exposes us to volatility in the prices and availability of these materials, and may result in our being susceptible to changes in geopolitical relationships. We may not be able to obtain a sufficient supply of raw materials or supplied components, on favorable terms or at all, which could result in delays in, or the inability to, manufacture our TRISO-X fuel and SMRs or result in increased costs.
We are dependent on the ability of our supplier partners to scale their production output to meet the requirements of our forecast. If our supplier partners cannot increase their production capacity to meet the demand, it could result in delays in our ability to manufacture our reactors at the rates required.
Certain key components of our SMR are currently manufactured outside the U.S. and we rely on the timely and cost-effective transportation of goods via ocean freight. Disruptions to global shipping networks, such as port congestion, vessel capacity shortages, labor strikes, extreme weather events, piracy, geopolitical tension, or new environmental regulations could significantly delay shipments, increase transportation costs, or impair our ability to meet customer demand. If such disruptions occur, we may be unable to secure alternative transportation in a timely manner, which could adversely affect our supply chain, customer relationships and financial performance.
Moreover, a major shipping accident could have a severe, negative impact on the delivery schedule and cost of our early projects, such as in the case of key components being lost at sea due to severe weather.
Additionally, the imposition of tariffs and impacts of inflation on raw materials or supplied components for our reactors could have a material adverse effect on our operations. Prolonged disruptions in the supply of any of our key raw materials or components, difficulty qualifying new sources of supply, implementing use of replacement materials or new sources of supply or any volatility in prices could have a material adverse effect on our ability to operate in a cost efficient, timely manner. Such prolonged disruptions could also cause us to experience cancellations or delays of scheduled launches, customer cancellations or reductions in our prices and margins, any of which could harm our business, financial condition, operating results and future prospects.
In particular, recent global trade tensions and policy shifts have created an unpredictable environment for businesses operating across international borders. Changes in trade agreements, sanctions, export controls, and customs regulations may limit our ability to source materials from certain countries or entities, potentially forcing rapid and costly adjustments to our supply chain. Trade policies can change with limited notice, making long-term planning difficult and increasing operational costs.
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While we attempt to mitigate these risks through diversification of our supplier base, inventory management strategies, and contractual protections, there can be no assurance that these measures will be effective. Any significant disruption to our supply chain resulting from tariffs or trade policy changes could have a material adverse effect on our business, financial condition, and ability to meet projected deadlines and milestones.
We depend on key executives and management to execute our business plan and conduct our operations. A departure of key personnel could have a material adverse effect on our business.
Our success depends, in significant part, on the continued services of our senior management team and on our ability to attract, motivate, develop and retain a sufficient number of other highly skilled personnel, including engineers, manufacturing and quality assurance, finance, marketing and sales personnel. Our senior management team has extensive experience in the energy industry, including nuclear, and manufacturing industries, and we believe that their depth of experience is instrumental to our continued success. The loss of any one or more members of our senior management team, for any reason, including resignation or retirement, could impair our ability to execute our business strategy and have a material adverse effect on our business and financial condition if we are unable to successfully attract and retain qualified and highly skilled replacement personnel.
Our business plan requires us to attract and retain qualified personnel including personnel with highly technical expertise. Were we not to be able to successfully recruit and retain experienced and qualified personnel, it could have a material adverse effect on our business.
Our future success depends in part on our ability to contract with, hire, integrate, and retain highly competent nuclear reactor and fuels focused engineers and scientists, and other qualified personnel. Competition for the limited number of these skilled professionals is intense. If we are unable to adequately anticipate our needs for certain key competencies and implement human resource solutions to recruit or improve these competencies, our business, financial condition, operating results and future prospects would suffer. Additionally, U.S. immigration policy may make it more difficult for qualified foreign nationals to obtain or maintain work visas. These visa limitations may make it more difficult and more expensive for us to hire the skilled professionals we need to execute our growth strategy and may adversely impact our business. If we are unable to recruit and retain highly skilled personnel, especially personnel with sufficient technical expertise to develop our reactors and fuel, we may experience delays, increased costs and reputational harm. additional requirements, which could adversely affect our results of operations.
We must complete nuclear grade material qualifications and obtain regulatory approvals for the use of various materials in our TRISO-X fuel and our reactor designs. This includes long lead time irradiation testing and analysis, which may require redesign or use of alternative suppliers if results are unsatisfactory. Further, certain key nuclear grade materials and components, such as graphite, are only produced in limited quantity and predominantly outside of the U.S. Cultivating expanded foreign or domestic U.S. supply chain manufacturing capacity for key materials and components depends on cooperation from government and supply chain partners that may result in shortages and delays if not accomplished within assumed timelines or costs. These key materials and components may also be particularly vulnerable to inflationary pressures and cost increases.
The equipment, components, and materials used in a nuclear power plant are subject to a heightened level of manufacturing and quality assurance scrutiny, in compliance with NRC regulations, applicable codes and nuclear industry standards. Moreover, it is critical to demonstrate in facility design and development that the materials used in the reactor facility that will be exposed to radioactive materials, performed in accordance with necessary design parameters. The heightened manufacturing and quality assurance requirements and regulatory oversight limit the number of potential suppliers from whom we can procure many types of equipment, components, and materials used in our reactors and within TX-1, as well as the types of facilities where we can test certain materials. We may not be able to obtain sufficient materials or supplied components to meet our manufacturing and operating needs, or obtain such materials on favorable terms, which could impair our ability to fulfill our orders in a timely manner or increase our costs of production.
Our suppliers’ ability to manufacture components for our fuel fabrication facilities is dependent upon sufficient availability of materials and possibly other supplied components, some of which are highly
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specialized and are being designed for first-of-a-kind or sole use in our fuel fabrication facilities. Any supply chain disruption incurred by our third-party suppliers or degradation in the quality and processes of our manufacturer partners, may result in delays, cost overruns or impairments to the development of our fuel fabrication facilities.
These suppliers and the key materials and essential components may be particularly vulnerable to price increases, as a result of supply and demand dynamics, inflation, the current administration’s implemented tariffs, and other price pressures. As a result, supplier delays, unexpected performance testing results, issues in the manufacturing process or procuring necessary materials, international procurement needs, regulatory compliance issues, component qualification issues or delays, increases in costs as a result of inflation or otherwise, and geopolitical considerations can all impact our ability to perform necessary R&D, assist a customer in licensing a reactor, license TX-1, assist customers in constructing and operating an X-energy reactor design, or construct and operate TX-1. Such prolonged disruptions could also cause us to experience cancellations or delays of scheduled projects, customer cancellations or reductions in our prices and margins, any of which could harm our business, financial condition, operating results and future prospects.
Our business is subject to the risks of earthquakes, fire, floods and other natural catastrophic events, global pandemics, and interruptions by man-made problems, such as network security breaches, computer viruses or terrorism. Material disruptions of our business or information system resulting from these events could adversely affect our operating results.
We are vulnerable to damage from catastrophic events, such as natural disasters, global pandemics, power loss, and similar unforeseen events beyond our control. Catastrophic events could disrupt our business operations, reduce or restrict our supply of products and services, incur significant costs to protect our employees and facilities, or result in regional or global economic distress, which may materially and adversely affect our business, financial condition, operating results and future prospects. Actual or threatened war, terrorist activities, political unrest, civil strife, and other geopolitical uncertainty could have a similar adverse effect on our business, financial condition, and results of operations. Any one or more of these events may adversely affect our operation results, or even for a prolonged period of time, which could materially and adversely affect our business, financial condition, and results of operations.
We cannot guarantee that we are adequately protected from the effects of earthquakes, fire, floods, typhoons, global pandemics, power loss, telecommunications failures, break-ins, war, riots, network security breaches, computer viruses, terrorist attacks or similar events. Any of the foregoing events may give rise to interruptions, damage to our property, delays in production, breakdowns, system failures, technology platform failures, or internet failures, which could cause the loss or corruption of data or malfunctions of our internet system as well as adversely affect our business, financial condition, and results of operations.
If a natural disaster, power outage or other event occurred that prevented us from using all or a significant portion of our headquarters, damaged critical infrastructure, or otherwise disrupted operations, it may be difficult or, in certain cases, impossible for us to continue our business for a substantial period of time. The disaster recovery and business continuity plans we have in place are unlikely to provide adequate protection in the event of a serious disaster or similar event. We may incur substantial expenses as a result of the limited nature of our disaster recovery and business continuity plans, which could have a material adverse effect on our business.
Our use of AI-based technology may present new risks and challenges to our business.
The rapidly evolving use of AI in our industry presents significant risks. If we fail to adopt, manage, and govern AI responsibly, our brand, regulatory approvals, operations, and financial results could be adversely affected.
We may explore the usage of third-party AI or machine learning (“ML”) platforms, offerings and tools, including AI chatbots and generative AI products (“AI/ML Technology”), in our internal operations. The development and use of AI/ML Technology present various privacy and security risks that may impact our business. AI/ML technology is subject to privacy and data security laws, as well as increasing regulation and scrutiny. The use of AI/ML technology and third-party open-source AI tools by our employees and consultants could pose risks relating to the protection of data, including the potential exposure of our
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proprietary, confidential or otherwise protected information to unauthorized recipients and the misuse of our or third-party intellectual property. Use of AI tools may result in allegations or claims against us related to violation of third-party intellectual property rights, unauthorized access to or use of proprietary information and failure to comply with open-source software requirements.
We have developed policies governing the use of AI/ML Technology by our employees, contractors, and authorized agents that are designed to protect our assets, including intellectual property, competitive information, personal information we may collect or process, and customer information. Any failure by our personnel, contractors or other agents to adhere to our policies could result in a violation of confidentiality obligations or applicable laws and regulations (including data privacy laws), jeopardize our intellectual property rights, cause or contribute to unlawful discrimination, result in the misuse of personally identifiable information, or introduce greater vulnerabilities to cybersecurity attacks or malware into our systems. We also could be subject to claims from providers of third-party AI/ML Technology that we are using their products, tools or outputs in a manner that is inconsistent with their terms of use, and such claims may result in costly legal proceedings.
The regulatory framework for AI/ML Technology is rapidly evolving as many federal, state and foreign government bodies and agencies have introduced or are currently considering additional laws and regulations. Additionally, existing laws and regulations may be interpreted in ways that would affect our use of AI/ML Technology, or could be rescinded or amended as new administrations take differing approaches to evolving AI/ML Technology. As a result, we cannot be certain that our policies or adherence to the existing laws and regulations will offer us sufficient protection or that the use of the AI/ML Technology will not harm our reputation, financial condition or operating results.
Several jurisdictions around the world, including Europe, the U.S. federal government and certain U.S. states, have proposed, enacted or are considering laws and policies governing the development, deployment and use of AI/ML, such as the EU Artificial Intelligence Act. It is possible that further new laws and regulations will be adopted in the U.S. and in other non-U.S. jurisdictions, or that existing laws and regulations, including competition and antitrust laws, may be interpreted in ways that would limit our ability to use AI/ML Technology for our business. Additionally, certain privacy laws extend rights to consumers (such as the right to delete certain personal data) and regulate automated decision making, which may be incompatible with our use of AI/ML. These obligations may make it harder for us to conduct our business using AI/ML, jeopardize our proprietary information, lead to regulatory fines or penalties, require us to change our business practices, retrain our AI/ML, or prevent or limit our use of AI/ML. If we cannot use AI/ML or our use is restricted, our business may be less efficient, or we may be at a competitive disadvantage. In addition, uncertainties regarding developing legal and regulatory requirements and standards may require significant resources to modify and maintain business practices to comply with laws in the U.S. and other jurisdictions concerning the use of AI/ML Technology, the nature of which cannot be determined at this time.
The use of third-party AI/ML Technology by our business partners and employees with access to our confidential information, including trade secrets, may continue to increase. This could lead to the misuse or disclosure of such information, which could negatively impact us, including our ability to realize the benefits of our intellectual property. The use of AI/ML Technology by our business partners may lead to cybersecurity risks, which could have a material adverse effect on our operations and reputation as well as the operations of any of our business partners. Finally, the use of AI/ML Technology also presents emerging ethical issues, and if our use of third-party AI/ML Technology becomes controversial, we may experience brand or reputational harm or legal liability or we may be at a competitive disadvantage.
Further, constraints or shocks in AI/ML Technology supply chains could increase costs or delay projects as we continue to rely on them for faster design and delivery of our solutions. Availability and pricing of advanced computing, specialized chips, and cloud capacity used for model development and simulation fluctuate with industry demand. Supply constraints could slow our digital engineering or analytics roadmaps or increase spend.
Any of these risks could be difficult to eliminate or manage and, if not addressed, could have a material adverse effect on our business, financial condition, operating results and future prospects.
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Risks Related to the Industry, Competition and General Economic Conditions
The market for our products and services is still in the early stages of growth and if it does not continue to grow, it grows more slowly than we expect, or fails to grow as large as we expect, our business, financial condition, operating results and future prospects may be adversely affected.
Our success depends substantially on the willingness of consumers to widely adopt our products and services and to pay associated prices for our products and services sufficient to meet our revenue and margin targets in terms of percentage and gross receipts. To be successful, we will have to educate consumers about our products and services through significant investment and provide quality products that are superior to the products provided by our competitors. It is difficult to predict the future growth rates, if any, and size of our market. We cannot assure you that our market will develop or that our products and services will be widely adopted. If our market does not develop, develops more slowly than expected, or becomes saturated with competitors, or if our products and services do not achieve market acceptance, our business, financial condition, operating results and future prospects could be adversely affected.
The market for Gen IV advanced nuclear reactor designs generating electric power and high-temperature heat is not yet established and may not achieve the growth potential we expect or may grow more slowly than expected.
The market for Gen IV advanced nuclear reactor designs such as the Xe-100 has not yet been established. SMRs utilizing advanced nuclear technologies have limited operational history and have not been proven at scale. Estimates for the total addressable market and our expectations, inclusive of recent updates, with regards to certain illustrative unit economics provided in this prospectus are based on a number of internal and third-party estimates, including our potential contracted revenue, the number of potential customers who have expressed interest in our SMRs, assumed prices and production and regulatory costs for our SMRs, our ability to leverage our current logistical and operational processes, assumptions regarding our technology and general market conditions. However, our assumptions and the data underlying our estimates may not be correct and the conditions supporting our assumptions or estimates may change at any time, reducing the predictive accuracy of these underlying factors. As a result, our expected performance as indicated by the illustrative unit economics provided in this prospectus, our estimates of the annual total addressable market and serviceable addressable market for our services, as well as the expected growth rate for the total addressable market and serviceable addressable market for our services, may prove to be incorrect.
In addition, our reactors, financial models and the illustrative unit economics included in this prospectus assume an anticipated plant life of 60 years. However, the licenses we receive from the NRC and other government authorities are limited to an initial term of 40 years, which is the maximum initial licensing term currently permitted. There is no assurance that we will be able to obtain license renewals or extensions, and if we are unable to do so, our reactors may be required to cease operations before the end of their useful lives, which could reduce the economic return of our projects, adversely affect customer demand, and negatively impact our business, financial condition, operating results and future prospects.
Our cost estimates are highly sensitive to broader economic factors, and our ability to control or manage our costs may be limited.
Capital and operating costs for the deployment of a first-of-a-kind reactor such as the Xe-100 are difficult to project, inherently variable and are subject to significant change based on a variety of factors, including site specific factors, customer offtake requirements, regulatory oversight, operating agreements, supply chain availability, local labor rates, inflation, detailed design, engineering and other factors. Opportunities for cost reductions with subsequent deployments are similarly uncertain. To the extent cost reductions are not achieved within the expected timeframe or magnitude, the Xe-100 and TRISO-X fuel may not be cost competitive with alternative technologies, which could materially and adversely affect our expected revenues, gross margins and the information included in the illustrative unit economics provided in this prospectus.
In addition, our cost estimates and project economics could be materially impacted by tariffs or other trade restrictions imposed on materials, components or equipment required for the construction and operation of our reactors and fuel facilities. While we do not expect to purchase certain key materials and components for several years, changes in tariff regimes or the imposition of new tariffs prior to or during our procurement period could significantly increase our costs or limit our ability to source necessary items. The potential for
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future tariffs or trade actions creates additional uncertainty in our cost projections and could adversely affect our competitiveness, margins and financial results.
The illustrative unit economics presented in this prospectus are estimates only, reflecting management’s current expectations and based on numerous assumptions. The illustrative unit economics presented in this prospectus may not be realized, and actual results could differ materially from the illustrative estimates presented.
Given our early stage of development, it is difficult to predict what results we might ultimately achieve. While we present “illustrative unit economics” in this prospectus, these figures are not projections, forecasts, targets or guidance for our future operating results but what we believe to be illustrative of potential revenues based on customer fees, and associated costs, based on information available to us as of the date of the prospectus. Our ability to actually achieve these unit economics and our business model depend on numerous factors and are based on numerous assumptions. In particular, the illustrative unit economics described in this prospectus are based on management’s current expectations and assumptions regarding customer fees, costs, and margins for a single plant. Actual results will depend on numerous factors outside our control, including customer negotiations and fee structures, market conditions, supply-chain costs and dynamics, manufacturing efficiency and utilization, financing terms and assumptions, customer adoption and actual operational performance, and are subject to the risks described below and elsewhere in this “Risk Factors” section. Any variation in these assumptions could cause our actual results to differ materially from the illustrative estimates presented.
Technology Fees. The illustrative unit economics reflect management’s current expectations regarding the amount and timing of technology fees we would expect to charge for customers’ use of our Xe-100 technology. These expectations are based on management’s internal benchmarking of IP licensing and industrial technology fees across various similar industries and sectors, together with the experience of our team and ongoing customer discussions. However, there is no directly comparable technology against which to benchmark the fee, and there can be no assurance that we would be able to collect from our customers fees that are typical in other industries or sectors. While we have had preliminary discussions with certain customers regarding a proposed fee estimate within the middle of the range reflected in the illustrative unit economics, we have not yet entered into any technology, intellectual property or related agreements, and we can provide no assurance that customers will accept our anticipated fee structure or pricing. In addition, because the technology fees relates to the use of our intellectual property, the associated cost to us is assumed to be zero.
The final fee will be negotiated on a case-by-case basis with each customer, based on numerous factors specific to each customer, and our actual revenues and customer fees from our technology fee may differ materially from the estimates in the illustrative unit economics, including as a result of the following factors, among others:
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customer negotiations that result in materially lower fees or delayed payment schedules;
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variations in project scope, timing, and customer profile that affect negotiated pricing;
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the potential emergence of competitors or alternative reactor technologies that exert downward pressure on fees;
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evolving market conditions, regulatory developments, and cost of capital for nuclear projects;
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customer reluctance to pay milestone-based technology fees prior to commercial operation;
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customers not being willing to pay higher fees for later stage plants, even after scaling and validation; and
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litigation, claims or other events that could result in an associated costs to us related to the use of our intellectual property.
If we are not able to receive our anticipated technology fee structure and pricing, it would have an impact on the amount of revenues, the timing of revenues and the percentage of revenues we anticipate generating pre-COD. For example, we expect approximately 15 – 35% of revenue in our reactor line of business to be realized prior to (and including) COD, and this includes both the technology fee and the services fees described below. If the actual technology fee we receive is lower, or customers are not willing to pay the assumed higher fees for later stage plants or on the milestone-based payment structure, then our illustrative pre-COD revenues
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and our illustrative percentage of pre-COD revenue will be lower, which could have a material and adverse impact on our business, results of operations and financial prospects, including our need to obtain additional financing or to generate sufficient liquidity or revenues to operate our business pre-COD.
Services. The illustrative unit economics reflect management’s current expectations regarding the amount and timing of services fees we would expect to charge customers for providing them with a suite of project development and operating services, including site selection, permitting, engineering, training, and procurement support and, following commercial operation date (“COD”), ongoing maintenance and operator training. Our assumptions regarding services pricing, timing, and margins are based on limited experience to date from the provision of initial strategic business and other services we have provided to customers and potential customers, as well as industry benchmarking and our team’s collective experience. However, there can be no assurance that we would be able to collect from our customers fees that are typical in other industries or sectors. To date, we have entered into only limited services or other agreements with potential customers, and we can provide no assurance that customers will accept our anticipated fee structure or pricing. The illustrative unit economics also assume that our customers will continue to rely on us as a service provider throughout the operational life of a plant, and there is no assurance that they will continue to do so. In addition, our services business depends on assumptions about customer demand, pricing, and long-term relationships that may not materialize.
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Our actual services revenues, customer fees, costs and margins may differ materially from the estimates in the illustrative unit economics, including as a result of the following factors, among others: our estimates are based on our limited history providing services at commercial scale, and actual costs to provide these services may be higher, and we may not be able to pass through all of the costs to our customers at our estimated fees and our estimated margin;
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we have only entered into a small number of services agreements with potential customers and those may not be representative of future revenues, fees, costs or margins that we are able to achieve;
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third-party service providers could enter the market, introducing price competition and thereby reducing revenue and fees, increasing costs and reducing margins;
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customers may elect to self-perform or contract with alternative vendors for site services, maintenance, or operator training; and
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our ability to maintain efficient staffing, supply-chain arrangements, and project execution will directly affect costs and profitability.
If our services assumptions prove inaccurate, our expected revenues, fees and margins could be materially reduced, and we may experience higher costs than currently anticipated. Because we do not construct, own, or operate plants, following COD, we depend entirely on customers’ continued engagement of our services to generate recurring revenue from our reactor line of business, with approximately 65-85% of revenue from our reactor line expected to be from the provision of long-term services offered post-COD. In addition, if the actual pre-COD services fees we receive are lower, then our illustrative pre-COD revenues and our illustrative percentage of pre-COD revenue will be lower, which could have a material and adverse impact on our business, results of operations and financial prospects, including our need to obtain additional financing or to generate sufficient liquidity or revenues to operate our business pre-COD. Similarly, if we do not generate the anticipated revenues post-COD, or if our costs are higher or margins are lower than anticipated, it could have a material and adverse impact on our business, results of operations and financial prospects, including our need to obtain additional financing or to generate sufficient liquidity or revenues to operate our business post-COD.
Fuel Pricing. The illustrative unit economics reflect management’s current expectations regarding the amount of TRISO-X fuel we will sell to customers, the price at which we will do so, and our related operating and capital costs. Our expectations assume that we will supply the initial core fuel load at COD and, following COD, provide recurring fuel supply for refueling over the life of each plant. We further assume that we will be the initial sole supplier of proprietary TRISO-X fuel. We have not yet entered into definitive fuel supply agreements, and there can be no assurance that customers will agree to the anticipated fee structure, pricing, or volume commitments. Customers may seek lower-cost alternatives, negotiate volume discounts, or purchase from other suppliers once alternative sources of TRISO-X fuel become available.
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Our actual revenues, fees, costs and margins from selling TRISO-X fuel to our customers may differ materially from the estimates in the illustrative unit economics, including as a result of the following factors, among others:
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the emergence of third-party suppliers or alternative fuel technologies that compete on price or performance;
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changes in uranium, feedstock, or manufacturing costs that adversely affect our margins;
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delays or cost overruns in developing and commissioning our fuel fabrication facilities, including the costs of labor, materials, and overhead;
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customer decisions to source fuel from other vendors once alternative supply chains are available; and
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the need to finance future fuel facilities at assumed utilization levels that may not be achieved.
If actual utilization of our manufacturing or fuel-fabrication facilities is lower than expected, or if costs increase due to inflation, regulatory delays, or operational inefficiencies, our margins could be materially reduced. In addition, the assumptions underlying the illustrative unit economics also exclude any costs or risk related to uranium procurement or inventory, feedstock procurement, or spent fuel management, which are borne by our customers. If we are required to bear any of these costs, or if fuel costs increase due to inflation, supply-chain constraints, or regulatory changes, our expected margins could be materially reduced. If our fuel pricing assumptions prove inaccurate, expected revenues, fees and margins could be materially reduced, and we may experience higher costs than currently anticipated. In addition, if the costs borne by our customers exceed their expectations, our reputation with our customers may be negatively impacted. Any of the foregoing could have a material and adverse impact on our business, results of operations and financial prospects, including our need to obtain additional financing or to generate sufficient liquidity or revenues to operate our business.
Our economics are based on an anticipated 60-year operating life of a reactor. While the Atomic Energy Act of 1954 limits initial licensing to 40 years, the current operating fleet was designed to operate beyond that limit. Similarly, the Xe-100 is designed with substantial margins to support operation beyond the initial 40-year licensing term. The NRC and industry recognized this margin and established the license renewal program to approve subsequent 20-year licensing periods. In license renewal, the NRC and industry focus efforts on reviewing the ability to manage the aging of nuclear power plants through performance programs. For the current operating fleet, since license renewal did not exist when they were initially licensed, the development of these aging management programs occurs for the first time at the time of license renewal.
For the Xe-100, since the design is intended to operate for 60 years, X-energy is designing the reactor with aging management in mind. The process to receive NRC approval for license renewal is well understood and the NRC has never denied a license renewal application. However, if the NRC does not approve our license renewal application, or if the anticipated operating life of a reactor is lower than anticipated, it could have a material and adverse impact on our business, results of operations and financial prospects.
Competition from existing or new companies could cause us to experience downward pressure on prices, fewer customer orders, reduced margins, the inability to take advantage of new business opportunities, and the loss of market share.
We operate in highly competitive markets and are subject to competition based upon product design, performance, project execution, constructability, pricing, quality, and services, from competing nuclear suppliers as well as from alternative means of producing electricity and/or heat. There are a number of advanced reactor designs, and some advanced reactor projects, under development in the U.S. Many of these designs are involved in preapplication review with the NRC. Our advanced design, projected product design performance, engineering expertise, and quality control have been important factors in our growth; nonetheless other companies providing competing technologies could capture customers or market share from us, which could have a material adverse effect on our business or financial condition.
In addition, some markets experience very low power prices due to a combination of subsidized renewables and low-cost fuel sources, and we may not be able to compete in these markets unless the benefits of the Xe-100 and our TRISO-X fuel are sufficiently valued in the market.
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For sales and/or deployments outside of jurisdictions with highly developed nuclear regulatory frameworks, some of our foreign competitors currently benefit from, and others may benefit in the future from, permissive regulatory and licensing regimes and/or from protective measures by their home countries where governments are providing financial support, including significant investments in the development of new technologies. Competitors based in Russia and China, such as China National Nuclear Corporation, currently operate commercial or near-commercial SMRs in their home countries, while competitors based in Korea are pursuing SMR development but do not currently operate commercial SMRs. Although their SMR designs have not been approved or licensed for use by the NRC or any other nuclear regulator in any jurisdiction outside of their native countries, those competitors may have a competitive advantage if they are able to obtain approvals, or if they can demonstrate to potential customers the value and benefits of their SMRs, particularly in jurisdictions that have less stringent nuclear regulatory requirements. These competitors may have access to greater sources of funding to develop and commercialize their SMRs than we do, whether as a result of potential competitive advantages or from supportive national governments. This market environment may result in increased pressures on our pricing and other competitive factors.
We believe our ability to compete successfully in designing, engineering and manufacturing our products and services at significantly reduced costs to customers does and will depend on a number of factors which may change in the future due to increased competition, our ability to meet our customers’ needs and the frequency and availability of our offerings. If we are unable to compete successfully, our business, financial condition, operating results and future prospects would be adversely affected.
Changes in the availability and cost of electricity, natural gas, oil and other forms of energy are subject to volatile market conditions that could adversely affect our business.
The prices for and availability of electricity, natural gas, oil and other energy resources are subject to volatile market conditions. We do not control these market conditions, which are, moreover, often affected by political and economic factors beyond our control. Decreases in energy prices, or changes in nuclear energy costs relative to other forms of energy, may adversely affect our business. To the extent that these uncertainties cause suppliers and customers to be more cost sensitive or to adjust their business plans and operations, decreased energy prices may have an adverse effect on our results of operations and financial condition.
The cost of electricity generated from nuclear sources may not be cost competitive with other electricity generation sources in some markets, which could materially and adversely affect our business.
U.S. electricity markets are heavily regulated at the federal, state and local levels. Many U.S. electricity markets price electric energy, capacity, and/or ancillary services on a competitive basis, with market prices subject to substantial fluctuations. Other markets require that power purchase decisions by electric utilities be subject to various competitiveness or prudence tests. As a result of competitive pressures, some electricity markets experience low marginal energy prices at certain times due to a combination of subsidized generating resources, competitors with low cost or no cost fuel sources, or market design features that create incentives for certain attributes or deliver revenue in unpredictable ways over time, and X-energy may not be able to compete in these markets unless the benefits of the low carbon, reliable and/or resilient energy generation provided by the Xe-100 are sufficiently valued. Even in electricity markets that price reliable capacity on a long term basis, there is no guarantee that our customers’ Xe-100 units will be sufficiently low cost so as to clear auction style capacity markets, and clearing a capacity auction in any one year is no guarantee of clearing in successive years.
Given the relatively lower electricity prices and higher availability of power in the U.S. when compared to many international markets, the risk associated with lower cost alternatives may be greater with respect to our business and operations in the U.S. Regardless of jurisdiction, however, failure of our SMRs to provide competitively priced electric energy, capacity and/or ancillary services could materially and adversely affect our business.
We and our customers operate in a politically sensitive environment, and the public perception of nuclear energy can affect our customers and us.
Successful execution of our business model is dependent upon public support for nuclear power in the U.S. and other countries. The risks associated with uses of radioactive materials, both in our proposed TX-1
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fuel fabrication facility, and subsequent fuel fabrication facilities and by our customers in future deployments of our SMR designs, and the public perception of those risks, can affect our business. Opposition by third parties can delay or prevent the licensing and construction of new nuclear power facilities and in some cases can limit the operation of nuclear reactors. Adverse public reaction to developments in the use of nuclear power could directly affect our customers and indirectly affect our business. Adverse public reaction, increased regulatory scrutiny and related litigation could contribute to extended licensing and construction periods for new nuclear reactors, delay construction schedules, or even shut down operations at already-constructed reactors. There have only been two new nuclear reactors built in the U.S. over the past 30 years, so there is not a good calibration today of the level of public acceptance or adverse reactions to nuclear power. Public perception of nuclear energy, as with most energy sources tends to be locally generated depending on the politics of the impacted communities rather than federally driven. As with other very visible technologies, a potential accident by any company or organization in the nuclear community can negatively impact the public perception of a particular project, such as our or our customer’s projects.
From a political perspective, while the current U.S. federal administration and select members of Congress are currently quite favorable towards nuclear energy, we cannot guarantee that such sentiment will last or that opponents of nuclear energy will not be successful in increasing the cost, complexity, or timelines associated with nuclear energy, whether in our operations or those of the broader industry and value chain. Any such delays may also impact the marketability of our technology internationally or our competitive position relative to others. For example, China already has a 500 MWt High Temperature Gas-cooled Reactor (HTGR) plant in operation, has a TRISO-X fuel facility, and is already marketing their technology internationally. Although Russian and Chinese competitors have SMR designs that have not been approved by the NRC or in any jurisdiction outside of their native countries, those competitors may have a competitive advantage if they are able to obtain approval comparable to the NRC’s Standard Design Approval, or if they can otherwise demonstrate to potential customers the value and benefits of their SMRs, particularly in jurisdictions that have less stringent regulatory requirements. In addition, these competitors may have access to greater government or other funding to develop and commercialize their SMRs than we do.
The direct and indirect impact on us and our customers from severe weather and other effects of climate change and the economic impacts of the transition to noncarbon based energy, could adversely affect our financial condition, operating results, and cash flows.
There are inherent climate-related risks wherever business is conducted. Our operations and properties, and those of our customers, may in the future be adversely impacted by flooding, wildfires, high winds, drought and other effects of severe weather conditions. Climate change is expected to increase the frequency and severity of such events, as well as contribute to chronic changes (such as changes to meteorological and hydrological patterns) that may result in similar risks. These events can force us or our customers to suspend operations at impacted properties and may result in significant damage to such properties. Even if these events do not directly impact us or our customers they may indirectly impact us and our customers through increased insurance, energy or other costs. The ongoing transition to non-carbon based energy also presents certain risks, including macroeconomic risks related to higher energy costs and energy shortages, among other things, which may also impact us directly or indirectly, such as through our supply chain. The speed and direction of the energy transition are also uncertain and subject to various competing pressures, including as a result of political, market, and other forces. If policymakers or the market coalesce around alternative energy technologies — such as renewables with battery storage, hydrogen, geothermal, or fossil fuels with carbon capture — such trend may adversely impact our ability to capture benefits associated with the energy transition. These direct and indirect impacts from climate change could adversely affect our financial condition, operating results, supply chain and cash flows.
We are subject to a series of risks related to sustainability matters.
There is ongoing scrutiny from investors, customers, policymakers and other stakeholders regarding companies’ consideration and management of climate change, human capital, and various other environmental and social matters. We from time to time engage in various initiatives (including disclosures) to address such matters and related stakeholder expectations; however, such initiatives entail costs and may not have the desired effect. Methodologies, standards, and data associated with sustainability disclosures are often complex and continuing to evolve. As with other companies, our approach to such matters is also expected to
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evolve, and we cannot guarantee that our approach will align with the expectations or preferences of any particular stakeholder. For example, in some instances, companies have been subject to accusations of greenwashing due to alleged deficiencies in disclosure, methodology, or actions. Additionally, in some instances, such stakeholders have different, or even conflicting, expectations, which can increase the cost and complexity of response. Failure to successfully navigate such expectations (including any regulatory requirements) may result in reputational harm, loss of customers or contracts, engagement from regulators or capital providers, or other adverse impacts to our business. Certain of our suppliers, customers, and other stakeholders are also subject to similar expectations, which may result in new or greater risks, including risks that may not currently be known to us.
Risks Related to X-energy’s Use of Technology
Technological changes could render our technology and products uncompetitive or obsolete, which could prevent us from achieving market share and sales.
Our failure to refine or advance our SMR technologies could cause our reactor technology to become uncompetitive or obsolete, which could prevent us from achieving market share and sales. We may need to invest significant financial resources in research and product development to keep pace with technological advances in the industry and to compete in the future; we may be unable to secure such financing. A variety of competing alternative technologies may be in development by other companies that could result in lower manufacturing or operating costs and/or higher performance than those expected for our technology. Our development efforts may be rendered obsolete by the technological advances of others, and other technologies may prove more advantageous for commercialization.
We and our third-party providers are subject to information technology and cyber security risks which could result in material adverse effects to our business, financial condition, operating results and future prospects, including damage to our reputation, material financial penalties, and legal liability.
We are increasingly dependent upon information technology systems, infrastructure and data to operate our business (collectively “IT Systems”). We own and manage some of these IT Systems but also rely on third parties for a range of IT Systems and related products and services. In the ordinary course of business, we collect, store and transmit confidential information (including but not limited to intellectual property, proprietary business information and personal information) (collectively, “Confidential Information”) through our IT Systems. It is critical that we do so in a secure manner to maintain the confidentiality and integrity of such Confidential Information. We also have outsourced elements of our operations to third parties, and as a result we manage a number of third-party contractors who have access to our Confidential Information.
The IT Systems and those of our contractors and consultants face numerous and evolving cybersecurity risks that threaten the confidentiality, integrity and availability of our IT Systems and Confidential Information, including breakdown or other damage or disruption from service interruptions, system malfunction, natural disasters, terrorism, war and telecommunication and electrical failures, as well as security breaches from inadvertent or intentional actions by our employees, contractors, consultants, business partners, and/or other third parties, or from cyberattacks by malicious third parties (including the deployment of harmful malware, ransomware, denial-of-service attacks, social engineering and other means to affect service reliability and threaten the confidentiality, integrity and availability of information).
Cyberattacks are expected to accelerate on a global basis in frequency and magnitude as threat actors are becoming increasingly sophisticated in using techniques and tools, including AI, that circumvent security controls, evade detection and remove forensic evidence. As a result, we may be unable to detect, investigate, remediate or recover from future attacks or incidents, or to avoid a material adverse impact to our IT Systems, Confidential Information or business. There can also be no assurance that our cybersecurity risk management program and processes, including our policies, controls or procedures, will be fully implemented, complied with or effective in protecting our IT Systems and Confidential Information. Furthermore, given the nature of complex systems, software and services like ours, and the scanning tools that we deploy across our networks and products, we regularly identify and track security vulnerabilities to include potential risk level and severity. We are unable to comprehensively apply patches or confirm that measures are in place to mitigate all such vulnerabilities, or that patches will be applied before vulnerabilities are exploited by a threat actor.
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While we have not experienced any material cyberattacks or other incidents to date, we cannot assure you that such incidents will not occur in the future, which could have a material adverse effect on our reputation, business, financial condition and results of operations. For example, we maintain databases comprised of our Xe-100 nuclear design technical engineering information and operations information, which have been and will continue to be used to design the Xe-100 reactors and will be utilized in “digital twin” construction and operations environments to allow for highly efficient construction and operations of these designs. If this database were to be lost or compromised, our ability to efficiently deploy and operate our reactors could be significantly impaired.
Furthermore, any adverse impact to the availability, integrity, or confidentiality of our IT Systems or Confidential Information could result in financial, legal, business, and reputational harm to us. For example, any such event that leads to unauthorized access, use, or disclosure of Confidential Information, including personal information related to our employees, could harm our reputation directly, compel us to comply with federal and/or state breach notification laws and foreign law equivalents, subject us to mandatory corrective action, and otherwise subject us to liability under laws and regulations that protect the privacy and security of personal information, which could result in significant legal and financial exposure and reputational damages that could potentially have an adverse effect on our business. Finally, we cannot guarantee that any costs and liabilities incurred in relation to an attack or incident will be covered by our existing insurance policies or that applicable insurance will be available to us in the future on economically reasonable terms or at all.
If we fail to continuously offer innovative products and services and keep pace with changes in technology, our fees and our ability to obtain new engagements will be adversely affected and our revenues and profitability will decline.
Our business depends, in part, on our ability to anticipate industry, business and technology trends that help businesses to become more competitive and profitable. To remain competitive, we will need to continue to develop new services and products for our clients that distinguish us from our competitors. We also will need to identify new and evolving technologies that will gain acceptance in the marketplace and develop relationships with new leaders in technology as they emerge. If we fail to accomplish these objectives, we may be unable to compete effectively for new engagements, which may cause our revenues and profitability to decline. We may also invest resources in new services that are not competitive or that do not gain wide acceptance from our clients, which may cause our profitability to decline. When providing innovative services that distinguish us from our competitors, we expect to be able to obtain higher margin fees. Over time, however, if our competitors begin to offer services which we may have developed or pioneered, we may experience decreases in the amount of fees we can charge for these services.
Risks Related to Ongoing and Future Changes to Our Reactor and Fuel Design
Our reactor and fuel designs have evolved over time and are expected to continue to change as we progress through development, regulatory review, and commercialization. The process of refining and optimizing our technology is ongoing and may result in material modifications to the design, configuration, or performance characteristics of our products. These changes may be driven by regulatory feedback, advances in technology, supply chain constraints, customer requirements, or lessons learned during prototyping, testing, and early deployment.
Any significant changes to our design may require additional engineering, testing, and regulatory review, which could result in increased costs, delays in our development timeline, or the need to repeat certain qualification or licensing activities. Design changes may also impact our ability to achieve standardization, scale manufacturing, or meet previously communicated performance, safety, or cost targets. Furthermore, customers or partners may delay purchase decisions or require renegotiation of terms in response to design changes, which could adversely affect our business prospects and financial condition.
There is also a risk that changes made to address one set of requirements may introduce new technical challenges or unforeseen issues, potentially impacting the commercial viability or regulatory acceptance of our products. If we are unable to effectively manage ongoing design changes, or if such changes result in negative perceptions among customers, regulators, or investors, our business, financial condition, and results of operations could be materially and adversely affected.
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If we are unable to scale our fuel fabrication facilities, our ability to manufacture pebble fuel will be adversely affected, which could have a material adverse effect on our business prospects, financial condition, results of operations and cash flows.
The Xe-100 requires pebble fuel in order to function, the manufacturing of which is not yet at scale. We may not be able to manufacture a sufficient amount of pebble fuel in order to support our reactors. Our ability to become profitable in the future will not only depend on our ability to successfully market the Xe-100 and TRISO-X fuel, but also to ensure we have a sufficient supply of fuel pebbles to support our business. If we are unable to efficiently design, manufacture, market, sell, distribute and service our pebble fuel, our margins, profitability and prospects would be materially and adversely affected.
Our ability to introduce new features, integrations, capabilities and enhancements is dependent on adequate research and development resources.
To remain competitive, we must maintain adequate research and development resources, such as the appropriate personnel and development technology, to meet the demands of the market. If we are unable to develop features, integrations, capabilities and enhancements internally due to certain constraints, such as employee turnover, a lack of management ability or a lack of other research and development resources, our business may be harmed. Moreover, research and development projects can be technically challenging and expensive. The nature of these research and development cycles may cause us to experience delays between the time we incur expenses associated with research and development and the time we are able to offer compelling features, integrations, capabilities and enhancements and generate revenue, if any, from such investment. If we expend a significant amount of resources on research and development and our efforts do not lead to the successful introduction or competitive improvement of features, integrations, capabilities and enhancements, it could harm our business, financial condition, operating results and future prospects. In addition, our failure to maintain adequate research and development resources or to compete effectively with the research and development programs of our competitors may harm our business, financial condition, operating results and future prospects.
Operating a nuclear reactor in an unusual environment, whether due to unusual siting or an industrial application, has additional risks and costs compared to conventional electric power applications.
We expect our initial deployment of the Xe-100 under the ARDP to include industrial heat applications. This deployment is expected to be the first instance of using SMR technology for such applications. Such a deployment will require additional overhead associated with the licensing process, configuration control of the plant, chemistry control, Tritium containment, minimum operating staff, training, security infrastructure, radiation protection, government reporting, and nuclear insurance, all of which may be cost prohibitive or require separate operating agreements to provide necessary nuclear overhead without disrupting industrial processes. While we have attempted to address such increases in our updated cost estimates, any additional costs or increased regulatory requirements may cause delays under our project timelines and costs and may have an adverse impact on our ARDP partner.
Additionally, our technologies are also designed to be able to serve customers in locations historically atypical for nuclear energy, whether due to being far away from urban infrastructure, in closer proximity to population centers, and/or areas that may experience more extreme planetary conditions. Such deployment may come with additional risks and costs, including beyond any projections we may have made, which may adversely impact our business.
Risks Related to X-energy’s Proprietary and Intellectual Property Rights
We rely heavily on our intellectual property portfolio. Our ability to maintain, protect or enforce our patents and other intellectual property rights may be challenged and is not guaranteed. If we are unable to protect our intellectual property rights, our business and competitive position may be harmed.
Our success depends in part on our ability to maintain, protect and enforce our intellectual property rights, including our patents in connection with our SMRs. We rely on a combination of the intellectual property protections afforded by patent, trademarks/service mark, copyright and trade secret laws in the U.S. and other jurisdictions, as well as contractual restrictions in our agreements such as confidentiality agreements,
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assignment agreements, and license agreements with our employees, consultants, suppliers, and other third parties with whom we have a business relationship, to protect, establish, maintain and enforce our intellectual property rights, including rights associated with our SMRs and related proprietary technologies. However, the steps we take to protect our intellectual property and other confidential information may not adequately secure our intellectual property rights, and we may not be able to prevent the unauthorized disclosure or use of confidential information. Furthermore, if any of our employees, consultants, suppliers, or other third parties with whom we have a business relationship breaches or violates the terms of any of these agreements, we may not have adequate remedies for any such breach or violation. It is also possible that our confidential or other proprietary information could be obtained by third parties as a result of breaches of our physical or electronic security systems. Even where remedies are available, enforcing a claim that a party illegally disclosed or misappropriated our confidential or other proprietary information is expensive and time consuming, and the outcome is unpredictable. In addition, we cannot be certain that our competitors will not independently develop same or similar technology, obtain information we regard as proprietary, or design around intellectual property rights of ours.
For example, on August 13, 2024, X-energy, through counsel, notified Ultra Safe Nuclear Corporation (“Ultra Safe”) of our belief that Ultra Safe could be infringing certain of our patents relating to fuel fabrication. Ultra Safe subsequently filed for bankruptcy and we have filed an objection and reservation of rights to Ultra Safe’s debtors’ bidding procedures and sale before the Delaware Bankruptcy Court, objecting to the potential sale of the certain assets believed by us to be infringing on our patents. While we are seeking to resolve the matter, an adverse outcome or prolonged litigation could materially impact our ability to operate or commercialize our technology.
Our success depends in large part on our ability to obtain and enforce patent protection for our SMRs. We either own or have license rights to certain intellectual property applicable to our SMRs and fuel technology, including issued patents and patent applications. However, merely holding patents or licenses to patents on our nuclear power reactors and fuel technologies is not a guarantee of protection or rights. Furthermore, we cannot be certain that our patent applications will result in patents being issued, or that our existing or future issued patents will afford protection against competitors with similar technology. During the patent prosecution process, a patent office may require us or our licensors to narrow the scope of the claims of our or our licensors’ patent applications. This may limit the scope of patent protection and our or our licensors’ ability to assert patent infringement if the patent is subsequently issued. In some cases, a patent may not be issued if we or our licensors are unable to overcome rejections from a patent office, which may have a material adverse effect on our ability to prevent others from commercially exploiting products similar to ours. By pursuing patent rights by filing a patent application, we or our licensors may lose trade secrets that would have otherwise been protected had a patent not been sought, and third parties may be able to exploit such published information in our patent application. Additionally, even if we obtain a patent in one jurisdiction (e.g., the U.S.), we cannot guarantee that we will obtain a corresponding patent in another jurisdiction (e.g., China) as patent laws differ from jurisdiction to jurisdiction. Additionally, maintaining and enforcing patent rights can involve complex legal and factual questions, and may be subject to litigation in some cases. For example, third parties may challenge the validity or enforceability of our or our licensors’ patents at a tribunal such as the Patent Trial and Appeal Board at the U.S. Patent and Trademark Office or in federal court. Third parties may prevail in invalidating a patent or preventing a patent application from being issued as a patent. Furthermore, issued patents or patent applications owned by third parties exist in the fields in which we have developed, are developing or will develop in the future our technology. In addition to the risk of infringing those patents, those patents may also be used as a basis to invalidate our patents or prevent our patent applications from issuing as patents.
Even if our patent applications succeed and we are issued patents, it is still uncertain whether these patents will be contested, circumvented, infringed upon, invalidated or limited in scope in the future. The rights granted under any issued patents may not provide us with meaningful protection or competitive advantages, and some foreign countries provide significantly less effective patent enforcement than in the U.S. In addition, the claims of our issued patents may not be broad enough to prevent others from developing technologies that are similar or that achieve results similar to ours. The intellectual property rights of others could also bar us from licensing and exploiting our issued patents. In addition, patents issued to us may be infringed or designed around by others and others may obtain patents that we need to license or design around,
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either of which would increase costs and may adversely affect our business, financial condition, operating results and future prospects.
We currently enjoy only limited geographical protection with respect to certain issued patents and may not be able to protect our intellectual property rights throughout the world.
We do not have worldwide patent rights for our SMRs and related proprietary technologies because intellectual property rights are territorial. Accordingly, we may not be able to protect our intellectual property rights in certain jurisdictions. Filing, prosecuting and defending patents on our SMRs in multiple jurisdictions can pose several challenges. First, procuring patent rights in multiple jurisdictions may be cost prohibitive because individual patent offices in different jurisdictions examine each patent application separately. Once a patent is issued, we or our licensors will also have the continued obligation of paying maintenance fees periodically to avoid patents from becoming abandoned or lapsed. Second, the breadth of claims in patents may vary from jurisdiction to jurisdiction. For instance, certain patent offices may require narrower claims, resulting in patent rights that are less extensive. Further, we may not be able to obtain patents in some jurisdictions even if we obtain patents in other jurisdictions. Accordingly, our competitors may operate in countries where we do not have patent protection and can freely use our technologies and discoveries in such countries to the extent such technologies and discoveries are publicly known or disclosed in countries where we have issued patents or patent applications.
Further, many countries have compulsory licensing laws under which a patent owner may be compelled to grant licenses to third parties. Many countries also limit the enforceability of patents against government agencies or government contractors. In these countries, the patent owner may have limited remedies, which could materially diminish the value of such patent. If we or any of our licensors are forced to grant a license to third parties with respect to any patents relevant to our business, our competitive position may be impaired, and our business and financial condition may be adversely affected.
We may be subject to intellectual property rights claims by third parties, which are extremely costly to defend, could require us to pay significant damages and could limit our ability to use certain technologies.
We cannot be certain the conduct of our business does not or will not infringe, misappropriate or otherwise violate the intellectual property rights of a third party. Third parties, including our existing and future competitors, may currently hold or obtain in the future patents, trademarks/service marks or other intellectual property rights that cover aspects of our proprietary technology or other intellectual property that would prevent, limit or interfere with our ability to develop our intellectual property and make, use, develop, import, offer to sell or sell our SMRs and related technology, which may have a materially adverse effect on our business and financial condition. From time to time, we have received and may in the future receive communications from holders of patents or other intellectual property rights inquiring whether we are infringing their intellectual property rights, seeking court declarations that we do not infringe their intellectual property rights or requesting us to obtain a license from them. If we are determined to have infringed a third party’s intellectual property rights, we may be required to do one or more of the following, among other thing: (i) cease selling, incorporating or using SMRs that are found to be infringing; (ii) pay substantial damages; (iii) pay for and obtain a license from the holder of the infringed intellectual property right, which may not be available on reasonable terms or at all; or (iv) redesign part or all of our technology. In the event of a successful claim of infringement against us and our failure or inability to obtain a license to the infringed technology, our business, financial condition, operating results and future prospects could be materially adversely affected. In addition, any litigation or claims, whether or not valid, could result in substantial costs and diversion of resources and management’s focus and attention.
We also license patents and other intellectual property from third parties, and we may face claims that the use of this intellectual property infringes the rights of other third parties. In such cases, we may seek indemnification from the licensors under our license contracts with those licensors, or other damages. However, our rights to indemnification or damages may be unavailable or insufficient to cover our costs and losses, depending on our use of the technology, whether we choose to retain control over conduct of the litigation, and other factors.
We review and assess third-party patents and other intellectual property rights relevant to our products and fuel fabrication processes. However, we may not identify all relevant third-party patents, or may incorrectly
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interpret their scope, relevance, or expiration. Any such oversight could expose us to infringement claims, require us to modify our technology, or limit our ability to develop, manufacture, or market our SMRs and related products. This could result in costly litigation, delays, or the need to obtain licenses on unfavorable terms, any of which could adversely affect our business, financial condition, and results of operations.
In addition, there are several circumstances under which a patent application may not be published and accessible to us or our licensors. For example, patent applications in the U.S. and many foreign jurisdictions are typically not published until 18 months after filing, but some patent applications in the U.S. may be maintained in secrecy until the patents are issued. Publications in the scientific literature also often lag behind actual discoveries. Therefore, we cannot be certain that others have not filed patent applications for technology covered by our issued patents or patents applications, or that we were the first to invent the technology or to file a patent application covering the technology. Our competitors may have filed, and may in the future file, patent applications covering our SMRs or technology similar to ours without us knowing. Any such patent application may have priority over our patent applications or patents, which could require us to procure rights to issued patents covering such technologies in order to avoid infringement claims.
We may be subject to claims of ownership and other rights to our patents and other intellectual property by third parties.
While we require our employees, consultants, contractors and other third parties to assign the intellectual property conceived by them to us in the event that the intellectual property is not automatically assigned (e.g., as work made for hire), those agreements may not be effective or honored, and obligations to assign intellectual property may be challenged or breached. Moreover, there may be some circumstances where we are unable to negotiate for such ownership rights, or where others misappropriate those rights.
We may be subject to claims that former or current employees, consultants, contractors or other third parties have an interest in our patents or other intellectual property. Litigation may be necessary to resolve these claims challenging inventorship and ownership. Furthermore, we may enter into agreements to clarify the scope of our rights in such intellectual property. If we fail in defending any such claims, in addition to paying monetary damages, we may lose exclusive ownership of, or the right to use or license, valuable intellectual property. Such an outcome could have a material adverse effect on our business. Even if we are successful in defending against such claims, litigation could result in substantial costs and be a distraction to management and other employees.
Risks Relating to Compliance with Law, Government Regulation and Litigation
Our business and the businesses of our customers are subject to the policies, priorities, regulations, mandates and funding levels of multiple governmental entities and may be negatively impacted by any change thereto.
We and our customers are subject to a wide variety of complex laws and regulations relating to various aspects of our business, including with respect to the use, possession and manufacturing of radioactive materials; design, manufacture, operations, marketing and export of nuclear technologies; employment and labor; tax; data security of the operational and information technology we use; the U.S. Foreign Corrupt Practices Act and other applicable anti-bribery laws; health and safety; zoning and environmental issues. All of our facilities and our customers’ projects are subject to various regulations regarding matters such as human health and safety, including, among others, wastewater, stormwater, air emissions, investigation and cleanup of contaminated sites, and storage of hazardous materials, including petroleum. We must also comply with the Occupational Safety and Health Act (OSHA). Laws and regulations at the international, federal, state and local levels frequently change and are often interpreted in different ways, especially in relation to new and emerging industries, and we cannot reasonably predict the impact from, or the ultimate cost of compliance with, current or future law or regulatory or administrative changes. We cannot guarantee that our measures to monitor these developments and the time and resources we spend to comply with these laws, regulations, and guidelines will be satisfactory to regulators or other third parties, such as our customers, who are also subject to extensive government regulation. Our efforts to comply with new and changing laws and regulations may result in increased general and administrative expenses and a diversion of management time and attention. Our insurance and compliance costs may increase as a result of changes in environmental, health and safety laws and regulations or changes in enforcement. Moreover, changes in law or the interpretation of existing
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laws, the imposition of new or additional regulations, or the enactment of any new or more stringent legislation that impacts our business could require us to change the way we operate and could have a material adverse effect on our sales, profitability, cash flows, financial condition, and lead to regulatory delays that could impact our ability to obtain licenses, certificates, authorizations, permits, approvals, and/or certifications from regulatory agencies (collectively “Regulatory Approvals”).
Failure to comply with laws, regulations or Regulatory Approvals may result in civil, criminal or administrative enforcement actions and penalties, the imposition of remedial obligations, installation of additional pollution control equipment, the issuance of orders enjoining our operations, private lawsuits, liability for property damage and personal injuries, or the suspension or revocation of those Regulatory Approvals, any of which would have a negative impact on our or our customers’ business and could prevent us from operating our business. With respect to our TX-1, we require regulatory approval from the NRC to construct and operate the facility under a nuclear materials license, in addition to local and state permitting requirements. Any of these Regulatory Approvals may be subject to denial, revocation or modification under various circumstances, including:
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failure to provide adequate financial assurance for closure;
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failure to comply with environmental, health and safety laws and regulations or permit conditions;
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local community, political or other opposition;
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executive action; and
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legislative action.
Failure on our or our customers’ part to comply with these laws and regulations, obtain the required Regulatory Approvals, or receive exemptions from such regulations when available could result in fines, penalties, or the inability to operate our business. Any delays in regulatory actions allowing us to manufacture our TRISO-X fuel could also adversely affect our ability to meet fuel contract requirements and thereby affect our financial performance.
Our SMRs are subject to regulations in all jurisdictions related to nuclear safety, environmental, health and safety and financial qualification. Regulatory Approvals, such as construction permits and operating licenses issued by the NRC, are necessary for our customers to construct and operate our SMRs. Our plans to deploy SMRs rely on timely receipt of such Regulatory Approvals in the jurisdictions in which we seek to do business. Such regulatory approval processes may be subject to change, can be technically challenging to address, may result in the imposition of conditions that impact the financial viability of our SMR products, and may also provide opportunities for third parties to lodge objections or seek more stringent requirements for our products that, in each case, could hinder or prevent developments of our or our customer’s projects.
Over the past several years, Congress has enacted laws that aim to put nuclear energy on a level playing field with respect to government incentives, tax credits, and other financial instruments to make nuclear energy more economically competitive with other energy sources. These incentives have been signed into law through the Infrastructure Investment and Jobs Act (IIJA) and the OBBBA. The benefits of these government financial tools are incorporated into our business model and that of our customers. The benefit from these subsidies are subject to cancellations and sunsets or changes to sunset provisions by both Congress and the current administration. The impact of changes to these financial benefits could materially impact the demand for our products.
The reduction or elimination of Section 48C, the Qualifying Advanced Energy Project Credit under the Inflation Reduction Act of 2022 (“48C”), investment tax credits (“48E”) and production tax credits (“45Y”) received through the U.S. government and Clean Technology Investment Tax Credits (“CT ITCs”) received through the Canadian government related to clean energy solutions could adversely affect our business and reduce the demand for our Xe-100 and other technologies.
Our business model and financial performance are significantly dependent on the availability of 48C, 48E, CT ITCs and 45Y. The reduction, denial, delay, recapture, or adverse modification of federal, state, or local tax incentives for clean energy — including 48C, 48E, 45Y, and CT ITCs — could adversely affect our business and reduce demand for our Xe-100 and other technologies. Our business model and the economics of
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customer projects, supplier expansions, and financing structures are significantly dependent on the availability, amount, timing, and monetization of these incentives.
Many of our counterparties rely on the receipt and monetization of 48C, 48E, CT ITCs or 45Y to finance or price projects involving our technologies. If these parties do not receive, cannot monetize, or later lose expected credits — due to changes in law, allocation caps, eligibility requirements, compliance failures, or market conditions — they may delay, renegotiate, or terminate contracts, reduce order sizes, or default on obligations to us. In addition, changes in transferability, direct pay rules, or market liquidity for these credits could further diminish project returns and impair demand.
Any reduction or unavailability of these incentives, or counterparties’ inability to obtain or monetize them as anticipated, would likely reduce the demand for the Xe-100, SMRs and nuclear energy solutions in general, which would have a material, adverse impact on our business, financial condition, operating results and future prospects.
The U.S. government’s budget deficit and the national debt, as well as any inability of the U.S. government to complete its budget or appropriations process for any government fiscal year could have an adverse impact on our business, financial condition, results of operations and cash flows.
The U.S. government’s budget deficit and the national debt, along with any negotiated resolution to increase or suspend the so-called debt ceiling, as well as any inability of the U.S. government to complete its budget process for any government fiscal year and consequently having to shut down or operate on funding levels equivalent to its prior fiscal year pursuant to a “continuing resolution,” could have an adverse impact on our business, financial condition, results of operations and cash flows.
Uncertainty will continue to exist regarding how future budget and program decisions will unfold, including the energy spending priorities of the U.S. government, what challenges budget reductions will present for the energy industry and whether annual appropriations bills for all agencies will be enacted for U.S. government fiscal 2026 and thereafter. Some of the changes in the political environment, include a change to the leadership within the current administration, and any resulting uncertainty or changes in policy or priorities and resultant funding. There can be no assurance that increases in funding we may currently experience will continue, and any plateau or reduction in funding for our programs could adversely affect our ability to execute our strategy, meet milestones, and achieve projected financial results. The U.S. government’s budget deficit and the national debt could have an adverse impact on our business, financial condition, results of operations and cash flows in a number of ways, including the following:
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the U.S. government could reduce or delay its spending on, reprioritize its spending away from, or decline to provide funding for the government programs in which we participate, or fail to increase funding as anticipated;
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U.S. government spending could be impacted by arrangements similar in effect to sequestration, which increases the uncertainty as to U.S. government spending priorities and levels; and
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we may experience declines in revenue, profitability and cash flows as a result of reduced or delayed orders or payments or other factors caused by economic difficulties of our customers and prospective customers, including U.S. federal, state and local governments.
Other contributing factors that could impact the company’s financial situation are rising interest rates as more U.S. government spending must be appropriated to servicing the national debt or the potential impact of tariffs on our supply chain as we begin to long lead procurements on certain materials and systems. Budget and program decisions made in this environment would have long-term implications for us and the entire nuclear energy industry.
We are required to comply with numerous laws and regulations, some of which are highly complex, and our failure to comply could result in fines or civil or criminal penalties or suspension or debarment by the U.S. government that could result in our inability to continue to work on or receive U.S. government contracts, which could materially and adversely affect our results of operations.
We must comply with laws and regulations relating to the formation, administration, and performance of U.S. government contracts, which affect how we do business. Such laws and regulations may potentially impose
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added costs on our business and our failure to comply with those laws and regulations may lead to civil or criminal penalties, including termination of our U.S. government contracts, including the ARDP contract, and/or suspension or debarment from contracting with federal agencies. Some significant laws and regulations that affect us include:
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the Federal Acquisition Regulation (the “FAR”), and agency regulations supplemental to the FAR, which regulate the formation, administration, and performance of U.S. government contracts. For example, the FAR 52.203-13 requires contractors to establish a Code of Business Ethics and Conduct, implement a comprehensive internal control system, and report to the government when there is credible evidence that a principal, employee, agent, or subcontractor, in connection with a government contract, has violated certain federal criminal laws, violated the civil False Claims Act, or has received a significant overpayment;
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the False Claims Act, which imposes civil and criminal liability for violations, including substantial monetary penalties, for, among other things, presenting false or fraudulent claims for payments or approval;
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the False Statements Act, which imposes civil and criminal liability for making false statements to the U.S. government;
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the Truthful Cost or Pricing Data Statute (formerly known as the Truth in Negotiations Act), which requires certification and disclosure of cost and pricing data in connection with the negotiation of certain contracts, modifications, or task orders;
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the Procurement Integrity Act, which regulates access to competitor bid and proposal information and certain internal government procurement sensitive information, and our ability to provide compensation to certain former government procurement officials;
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laws and regulations restricting the ability of a contractor to provide gifts or gratuities to employees of the U.S. government;
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post-government employment laws and regulations, which restrict the ability of a contractor to recruit and hire current employees of the U.S. government and deploy former employees of the U.S. government;
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laws, regulations, and executive orders restricting the handling, use and dissemination of information classified for national security purposes or determined to be “controlled unclassified information” or “for official use only” and the export of certain products, services, and technical data, including requirements regarding any applicable licensing of our employees involved in such work;
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laws, regulations, and executive orders regulating the handling, use, and dissemination of personally identifiable information in the course of performing a U.S. government contract;
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international trade compliance laws, regulations and executive orders that prohibit business with certain sanctioned entities and require authorization for certain exports or imports in order to protect national security and global stability;
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laws, regulations, and executive orders governing organizational conflicts of interest that may restrict our ability to compete for certain U.S. government contracts because of the work that we currently perform for the U.S. government or may require that we take measures such as firewalling off certain employees or restricting their future work activities due to the current work that they perform under a U.S. government contract;
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laws, regulations and executive orders that impose requirements on us to ensure compliance with requirements and protect the government from risks related to our supply chain;
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laws, regulations and mandatory contract provisions providing protections to employees or subcontractors seeking to report alleged fraud, waste, and abuse related to a government contract; and
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the FAR Cost Accounting Standards and Cost Principles, which impose accounting and allowability requirements that govern our right to reimbursement under certain cost-based U.S. government contracts and require consistency of accounting practices over time.
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In addition, the U.S. government adopts new laws, rules, and regulations from time to time that could have a material impact on our results of operations. Adverse developments in legal or regulatory proceedings on matters relating to, among other things, cost accounting practices and compliance, contract interpretations and statute of limitations, could also result in materially adverse judgments, settlements, withheld payments, penalties, or other unfavorable outcomes.
Our performance under our U.S. government contracts and our compliance with the terms of those contracts and applicable laws and regulations are subject to periodic audit, review, and investigation by various agencies of the U.S. government, and the current environment has led to increased regulatory scrutiny and sanctions for non-compliance by such agencies generally. In addition, from time to time we may report potential or actual violations of applicable laws and regulations to the relevant governmental authority. Any such report of a potential or actual violation of applicable laws or regulations could lead to an audit, review, or investigation by the relevant agencies of the U.S. government. If such an audit, review, or investigation uncovers a violation of a law or regulation, or improper or illegal activities relating to our U.S. government contracts, we may be subject to civil or criminal penalties or administrative sanctions, including the termination of contracts, forfeiture of profits, the triggering of price reduction clauses, withholding or suspension of payments, fines and suspension, or debarment from contracting with U.S. government agencies. Such penalties and sanctions are not uncommon in the industry, and there is inherent uncertainty as to the outcome of any particular audit, review, or investigation. If we incur a material penalty or administrative sanction or otherwise suffer harm to our reputation, our profitability, cash position, and future prospects could be materially and adversely affected.
Further, if the U.S. government were to initiate suspension or debarment proceedings against us or if we are indicted for or convicted of illegal activities relating to our U.S. government contracts following an audit, review, or investigation, we may lose our ability to be awarded contracts in the future or receive renewals of existing contracts for a period of time which could materially and adversely affect our results of operations or financial condition. We could also suffer harm to our reputation if allegations of impropriety were made against us, which would impair our ability to win awards of contracts in the future or receive renewals of existing contracts.
Uncertain global macro-economic and political conditions could materially adversely affect our results of operations and financial condition.
Our results of operations are materially affected by economic and political conditions in the U.S. and internationally, including inflation, deflation, interest rates, availability of capital, energy and commodity prices, trade laws and the effects of governmental initiatives to manage economic conditions. Current or potential customers may delay or decrease spending on our products and services as their business and budgets are impacted by economic conditions. The inability of current and potential customers to pay us for our products and services may adversely affect our earnings and cash flows.
We are subject to stringent U.S. export and import control laws and regulations. Unfavorable changes in these laws and regulations or U.S. government licensing policies, our failure to secure timely U.S. government authorizations under these laws and regulations, or our failure to comply with these laws and regulations could have a material adverse effect on our business, financial condition, and results of operations.
The inability to secure and maintain required export licenses or authorizations could negatively impact our ability to compete successfully or market our SMR technology and TRISO-X fuel for commercial applications outside the U.S. For example, if we were unable to obtain or maintain our licenses to export certain nuclear hardware, software, source code, or technical assistance, we would be effectively prohibited from exporting our SMR and TRISO-X fuel technology to non-U.S. locations, limiting our customer base to the U.S. and providing a competitive advantage to international SMR suppliers. In such cases, these restrictions could also require us to implement design changes to our SMRs to address issues with our domestic supply chain, which may increase costs or result in delays in delivery of new plants and subsequent additional SMRs when ordered. Certain key components of our SMRs are currently manufactured outside the U.S., and the imposition of sanctions, tariffs, or material changes in import and export requirements on a nation-by-nation basis, on materials or supplied components for our SMRs could have a material adverse effect on our operations. Additionally, we may require U.S. approvals in order to import certain materials and components
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that may be predominantly produced outside of the United States. Failure to comply with import and export requirements and regulations could expose us to civil or criminal penalties, fines, investigations, more onerous compliance requirements, loss of export privileges, debarment from government contracts or limitations on our ability to enter into contracts with the U.S. government. Any changes in export control regulations or U.S. government licensing policy, such as that necessary to implement U.S. government commitments to multilateral control regimes, may restrict our operations. Any delays, conditions or unexpected requirements may increase costs for us or our customers and may result in uncertainty regarding the ability to deploy our technology in a predictable way, which may adversely impact our competitiveness.
We are part of the highly regulated nuclear power industry. Our fuel designs differ from fuels currently licensed and used by commercial nuclear power plants, and our SMR designs similarly differ from reactors currently in operation, including with respect to potential industrial applications. As a result, the regulatory licensing and approval process for our nuclear power plants and for others that operate with our nuclear fuels will be first-of-a-kind and therefore may experience delays and increased costs as part of the regulatory review process. Industry acceptance of our nuclear fuels may also be hindered.
All entities that operate nuclear power facilities, fabricate nuclear fuel, or transport nuclear materials in the U.S. are subject to the jurisdiction of the NRC (except for those facilities and applications separately regulated by the DOE or the U.S. Department of Defense (the “DOD”)), and entities performing the same activities in other countries are subject to regulation by the NRC’s counterparts around the world. Our SMR designs also differ significantly from the reactors used today by commercial nuclear power facilities. These differences may result in a more extensive and prolonged review by the NRC and its counterparts around the world, potentially causing delays in fuel and reactor development program and in commercialization.
TRISO-X fuel cannot be used in existing nuclear reactors, and no currently available commercial fuel will work in our SMRs. Our fuel development timeline depends on the relevant nuclear regulator accepting and approving technical information and documentation that is generated during the fuel qualification program. There is a risk that regulators may require additional information regarding the fuel’s behavior or performance that could necessitate unplanned analytical or experimental work, resulting in schedule delays and increased research and development costs. Similarly, our reactor development timeline depends on the relevant nuclear regulator accepting and approving technical information and documentation about our reactor designs in the course of any design-specific licensing, certification, approval or similar process, or facility-specific licensing. There is a risk that regulators may require additional information regarding the reactor’s behavior or performance that could cause delays and additional costs. They may impose operational restrictions, such as lower fuel burnup limits, power levels, or more frequent maintenance and testing of components, which could adversely affect the commercial viability of our products.
We must obtain governmental licenses to possess and use radioactive materials, including isotopes of uranium, in our TX-1 operations. Failure to obtain or maintain, or delays in obtaining, such licenses could impact our ability to fabricate TRISO-X fuel for our customers, who will initially be reliant on us for TRISO-X fuel, and have a material adverse effect on our business, financial condition and results of operation.
The NRC has not yet issued a license for the Company’s TX-1, a facility intended to manufacture the fuel for our reactor designs and for other advanced reactor designs that utilize coated particle fuel. While an application is currently under review by the NRC for TX-1, delays in the NRC licensing review (due to government shutdowns or otherwise), or failure to obtain or to maintain TX-1 license upon issuance, could interfere with or prevent provision of our TRISO-X fuel to initial and subsequent Xe-100 reactors, inhibit interest in our reactors by future customers, impair our ability to produce and market other coated particle fuels, or impact our ability to begin plans for TX-2, our second facility. We also face the risk that the NRC could impose conditions in the license that are not acceptable to us, which could materially and adversely affect our business and the commercial viability of our nuclear fuel products.
Given the nature and length of the permitting process, significant turnover and organizational changes within the NRC’s workforce, including at the Commission, project management, and technical staff levels could cause a reduced and transitioning workforce and could lengthen review timelines — particularly in light of the increasing number of applications being submitted to the NRC by other companies. The combination
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of staffing adjustments and a heavier workload may result in delays in the review and approval of our permit applications, which would negatively impact our business and ability to develop our and our customers’ projects.
The operations of our planned TX-1 facility in Tennessee, and any future fuel fabrication facilities, will be highly regulated by U.S. federal and state level governmental authorities, including the NRC as well as the State of Tennessee and any other state jurisdictions in which we may establish operations. Our operations could be significantly impacted by changes in government policies and priorities.
The NRC has the authority to issue notices of violation for violations of the Atomic Energy Act of 1954, as amended (the “Atomic Energy Act”), NRC’s regulations and conditions of licenses, certificates of compliance, and orders. The NRC has authority to impose civil penalties (the maximum amount of which is adjusted annually to account for inflation) or additional requirements and to order cessation of operations for violations of these requirements. Penalties under the NRC regulations and applicable agency guidelines could include substantial fines, imposition of additional requirements, or withdrawal or suspension of licenses or certificates. Any penalties imposed on us could adversely affect our results of operations and liquidity. The NRC also has the authority to issue new regulatory requirements or to change existing requirements. Changes to the regulatory requirements also could adversely affect our results of operations and financial condition.
Our TX-1 in Oak Ridge, Tennessee will also be regulated by the State of Tennessee pursuant to Atomic Energy Act authority transferred under the NRC’s Agreement State Program and applicable state laws and regulations. Any future fuel fabrication facilities will be highly regulated in the location in which they are located.
Additionally, certain aspects of our current fuels R&D activity take place within DOE’s Oak Ridge National Laboratory (separate and apart from our TX-1 within the City of Oak Ridge). These activities are subject to DOE regulation and contractual requirements. Changes to those requirements could also materially affect our operations.
Changes in federal, state or local government laws, regulations, policies and priorities can impact our nuclear fuel operations. These could include changes in interpretations of regulatory requirements, increased inspection or enforcement activities, changes in budgetary priorities, changes in tax laws and regulations and other government actions or inaction. Any of these local, state and federal agencies may have the authority to impose civil and criminal penalties and our designs, facilities and projects must be approved by various regulatory bodies and to date, have not been approved. The public has the ability to intervene in licensing proceedings before the NRC for a fuel fabrication facility or a reactor.
The Xe-100 design has not yet been approved or licensed for use at any site by the NRC or any other national regulatory body, and approval or licensing of these designs is not guaranteed. Under the Atomic Energy Act and the implementing NRC regulations, members of the public, including state, local or tribal governments, have the right to request a public hearing or file a petition to intervene in connection with the NRC’s review of a license or permit application. Such requests may oppose the issuance of a license or permit in whole, or challenge specific aspects of the application or the NRC’s review. These proceedings can be complex and time-consuming, requiring the devotion of significant management attention and incur substantial legal and technical expenses to prepare responses, participate in hearings and address intervenor contentions. These proceedings may also delay or prevent the issuance of required Regulatory Approvals for any of our or our customer’s projects, including TX-1 or a customer’s Xe-100. The outcome of such proceedings is inherently uncertain and could result in the imposition of additional licensing conditions, or, in some cases, the denial of a Regulatory Approval. Any such delays or adverse outcomes could materially affect the timing, cost and feasibility of the projects and operations. Additionally, these hearing processes may also have adverse impacts on the local population’s perception of the safety of our facilities adversely impacting their timely deployment and efficient operations.
For example, as of August 12, 2025, one such public entity has filed a petition to intervene and request a hearing in connection with the pending application for a construction permit for one of our customer’s projects which will utilize our SMR technology under NRC Docket No. 50-614-CP. The petition challenges certain safety and environmental findings contained in the construction permit application. As of the date of this filing, the NRC has not yet acted on the petition. In addition, the NRC has received admissible contentions
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from Waterkeepers, an advocacy group, related to their opposition of our fuel fabrication facility plans. Should such a petition result in delay or denial of regulatory approvals, our business would be materially adversely impacted. We are also subject to Canadian regulatory approval processes for a portion of our business seeking approval in Canada. We must work through material parts of the Canadian review processes and engage with the NRC to address technical, policy, and programmatic matters ahead of formal application reviews for new projects.
To date, the Xe-100 has not yet been licensed, certified or approved by the U.S. NRC, U.K. Office for Nuclear Regulation (“ONR”) or the Canadian Nuclear Safety Commission (“CNSC”), and no currently operating NRC or CNSC-regulated reactor uses high temperature gas-cooled reactor technology or our TRISO-X fuel.
If the NRC, ONR or CNSC disagrees with our, or our customers’, licensing approach or the technical bases supporting the nuclear safety and environmental impact evaluations, the construction and operating license application processes could take longer than currently expected, or a license may not be granted at all, which would materially and adversely affect our business. Further, the NRC or CNSC could impose conditions in a license that are not favorable or acceptable to us or our customers, which could materially and adversely affect our business. Any delays, conditions or unexpected requirements may increase costs for us or our customers and may result in uncertainty regarding the ability to deploy our technology in a predictable way, which may adversely impact our competitiveness.
Since taking office in January 2025, President Trump has announced, revised, paused, and enacted various executive orders and tariffs which could have wide-reaching economic and regulatory impact, including but not limited to causing the NRC to change its regulatory standards and thresholds. Any unexpected changes to the NRC’s requirements may result in substantial delay or increased costs for us or our customers, which may adversely impact our competitiveness.
Even if the Xe-100 is licensed in the U.S., U.K. and Canada, we must still obtain approvals on a country-by-country basis to deploy this reactor technology, which approvals may be delayed or denied or which may require modification to our design.
Even if the Xe-100 is licensed, certified and/or approved in the U.S., U.K. and Canada, if we are to deploy our technology in other countries, we must first obtain regulatory approvals for our technology in those countries. The regulatory framework to obtain approvals is complex, varies from country to country, and may involve authorities on a subnational or local level. Timelines are likely to be longer for initial deployments of our technology in any jurisdiction, as regulatory agencies may not be familiar with our technology and how it differs from the technology used in legacy nuclear power facilities. Moreover, other countries’ approval processes may differ markedly from the NRC process or the CNSC process, or they may require that we alter aspects of our design before providing approval. Design modifications to meet country-specific requirements could adversely impact our ability to achieve standardization and therefore increase design, construction, and/or operational costs. Denial or delay in approvals abroad could materially and adversely affect our business outside of the U.S. and Canada.
Our operations involve the use, transportation and disposal of toxic, hazardous and/or radioactive materials and could result in liability without regard to fault or negligence.
Our operations involve the use, transportation, and disposal of toxic, hazardous and radioactive materials. A release of these materials could pose a health risk to humans, plants and animals or the environment. If an accident were to occur, its severity would depend on the volume and location of the release and the speed of corrective action taken by emergency response personnel, as well as other factors beyond our control, such as weather and wind conditions.
Under federal, state and local laws and regulations, a current or former owner or operator of real property may be liable for costs to remediate contamination resulting from the presence or release of hazardous substances, wastes or petroleum products. These laws and regulations continue to evolve and have generally become more stringent over time. The costs associated with remediating contamination could be substantial, and liability under such laws is strict, joint and several and may attach whether or not the owner or operator knew of or caused such contamination. Moreover, the presence of contamination may expose us to third-party
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claims for property damage or bodily injury, subject our properties to liens in favor of the government for damages and cleanup costs, impose restrictions on the manner in which we use our properties, and materially adversely affect our ability to sell, lease, insure or develop our properties. We also may be liable for costs of remediating third-party disposal sites to which we arranged for the disposal or treatment of hazardous substances without regard to whether such disposal occurred in compliance with environmental laws. These matters could have an adverse effect on our financial condition.
Additionally, we may be responsible for decontamination or decommissioning of facilities where we conduct, or previously conducted, operations. Activities of our contractors, suppliers or other counterparties similarly may involve toxic, hazardous, and radioactive materials, and we may be liable contractually, or under applicable law, to contribute to remedy damages or other costs arising from such activities, including the decontamination or decommission of third-party facilities.
In the U.S., the nuclear liability law codified at 42 U.S.C. 2210 (along with subsequent amendments, the “Price Anderson Act”) and applicable NRC regulations and corresponding insurance requirements channel liability to the nuclear operator of a nuclear power plant for third-party offsite damages caused by a nuclear incident or a precautionary evacuation due to a possible or actual nuclear incident. U.S. law is substantially similar in effect to global nuclear liability regimes wherein operators are subject to robust liability channeling and financial protection regimes, such as required insurance policies or government indemnification, to cover the operator’s financial risk in the event of a nuclear incident that gives rise to third-party offsite liability. If, however, an incident or precautionary evacuation is not covered under such a nuclear liability limiting regulatory framework we could be financially liable for damages arising from such incident or evacuation, which could have an adverse effect on our results of operations and financial condition.
The Price Anderson Act does not, however, cover onsite loss or damage to property due to a nuclear incident. Rather, the NRC, like many nuclear regulators around the world, requires nuclear operators to maintain onsite property damage insurance for loss or damage to property due to a nuclear incident. If an incident resulting in onsite property damage is not otherwise covered by the mandatory insurance policy maintained at the facility or the damages exceed policy coverage limits, then we could be potentially liable for damages arising from such incident, which could have an adverse effect on our results of operations and financial condition. We cannot provide assurance that any insurance we obtain will be adequate to cover our losses or liabilities or that such coverage will continue to be available, or available on acceptable terms or at acceptable rates.
There is no assurance that our contractual limitations on liability will be effective in all cases or in all jurisdictions. The costs of defending against a claim arising out of a nuclear incident or precautionary evacuation not otherwise covered by insurance, and any damages awarded as a result of such claim, could adversely affect our results of operations and financial condition.
Unresolved spent nuclear fuel storage and disposal issues and associated costs could have a significant negative impact on X-energy’s business operations if potential Xe-100 customers view the risks associated with these issues and costs as unacceptably high. Additionally, U.S. policy related to storage and disposal of used fuel from our power plant and/or negative customer perception of risks relating to these policies could have a significant negative impact on our business prospects, financial condition, results of operations and cash flows.
During the licensing process, a nuclear power plant operator must indicate how it will decommission its power plant and must have a “standard agreement” with the DOE related to the storage of the fuel waste created during its operating life. Therefore, the requirement for our customers’ facilities to establish the disposal of fuel may create challenges related to timeline and optimal use of our TRISO-X fuel. The Nuclear Waste Policy Act (“NWPA”) of 1982 requires the DOE to take title to, and to provide for the permanent geologic disposal of, spent nuclear fuel (“SNF”) and associated high-level nuclear radioactive waste (“HLW”) generated by domestic nuclear reactors. In 1987, Congress amended the NWPA to designate Yucca Mountain, in Nevada, as the only site that the DOE could consider for a permanent repository. The DOE has suspended the Yucca Mountain licensing process due to lack of congressional appropriations, but the site remains designated in federal law. Under the NWPA and the Standard Contracts DOE has entered into with nuclear utilities, DOE remains obligated to provide for permanent disposal of all SNF and HLW. Interim storage of SNF and HLW is authorized under the NWPA and NRC regulations and requires the construction and maintenance of NRC licensed SNF/ HLW storage facilities. While the costs of developing and maintaining these interim
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storage facilities can have a significant effect on the costs associated with waste storage and disposal for nuclear reactors, including X-energy’s reactors, these costs could themselves be impacted by the timing of the opening of a disposal facility, as well as any possible future changes to the interim storage or transportation requirements for SNF and other forms of HLW, and the extent to which operators are able to continue to successfully recover costs from DOE through breach-of-contract litigation for its continued failure to provide for permanent disposal.
There are currently two consolidated interim storage (“CIS”) facilities under development in the U.S. for the interim storage of SNF/HLW. Both facilities — Holtec International’s HI-STORE CIS in New Mexico and Interim Storage Partners’ facility in Texas — have been issued licenses by the NRC for construction and operation. These licenses were challenged in federal court, and in June 2025, the U.S. Supreme Court upheld the NRC’s authority to issue the licenses; however, further engagement with the states and DOE is necessary to construct the projects. It is possible that SNF/HLW generated at an X-energy reactor could be stored at one of these CIS facilities; however, it is also possible that these CIS facilities are never built or become operational, or are unable to store such waste from an X-energy reactor, in which case, the waste would need to be stored onsite or at another interim SNF storage facility until another disposal option became available, such as a U.S. government-determined permanent national repository or other government storage facility.
The establishment of a national repository for the storage and/or permanent disposal of SNF, such as the one previously considered at Yucca Mountain, Nevada, the timing of such a facility’s opening and the ability of such a facility to accept waste from an X-energy reactor, and any related regulatory action, could impact the costs associated with our Xe-100 customers’ storage and/or disposal of SNF/HLW. Likewise, the establishment of a CIS for the storage of SNF/HLW, the timing of such a facility’s opening and being able to accept waste from an X-energy reactor, and any related regulatory action, could impact our customers’ costs associated with storage of SNF/HLW. These waste storage issues, and changes to the current waste disposal practices or changes to reactor operators’ ability to recover storage costs from DOE through litigation, could be material to X-energy’s operations if potential customers view waste disposal as problematic, detrimental or a negative factor when considering an investment in an X-energy reactor.
Our SMRs may not qualify as low-emissions or emissions-free pursuant to regulatory or incentive frameworks that consider emissions on a lifecycle basis or that otherwise account for fuel cycle emissions or energy consumption.
While our SMRs directly generate virtually no air emissions, including greenhouse gas emissions, during operations, our SMRs may nonetheless not qualify as providers of emissions-free, carbon-free, low-carbon or similar generating resources under emissions-limitation schemes that assess emissions on a lifecycle basis or that otherwise consider emissions from energy consumed in our fuel cycle because of the use of carbon in our TRISO-X fuel production and because our TRISO-X fuel and its feedstocks require substantial amounts of energy to produce. Our fuel fabrication facilities and our suppliers’ facilities may rely on the local electric grid and its mix of generating sources for electricity or may rely on contracted supply that does not provide a choice among electric generation sources. We cannot control the generation and electricity purchasing decisions of local electric utilities and their suppliers or of electric suppliers to our third-party partners. Certain regimes, such as various sustainability “taxonomies,” may also consider eligibility based on a wider array of environmental objectives, which we cannot guarantee we or our customers will be able to meet. The failure of our SMRs to qualify for inclusion in emissions reduction or climate change related emissions control schemes, or emissions-based incentive programs may result in higher costs or lower revenues for us or our customers, as well as eligibility for financing from capital providers focused on certain sustainability criteria, and may adversely impact the demand for our products from our customers, which could materially and adversely affect our business, financial condition, operating results and future prospects.
Changes in effective tax rates or adverse outcomes resulting from examination of our income or other tax returns could adversely affect our results of operations and financial condition.
We are subject to taxation by U.S. federal, state, and local tax authorities. Our future effective tax rates could be subject to volatility or adversely affected by a number of factors, including:
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allocation of expenses to and among different jurisdictions;
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changes to our assessment about our ability to realize, or in the valuation of, our deferred tax assets that are based on estimates of our future results, the prudence and feasibility of possible tax planning strategies, and the economic and political environments in which we do business;
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expected timing and amount of the release of any tax valuation allowances;
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tax effects of stock-based compensation;
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costs related to intercompany restructurings;
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changes in tax laws, regulations, or interpretations thereof;
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the outcome of current and future tax audits, examinations, or administrative appeals;
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lower than anticipated future earnings in jurisdictions where we have lower statutory tax rates and higher than anticipated future earnings in jurisdictions where we have higher statutory tax rates; and
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limitations or adverse findings regarding our ability to do business in some jurisdictions.
Any changes in U.S. taxation may increase our effective tax rate and harm our business, financial condition, and results of operations. In particular, new income or other tax laws or regulations could be enacted at any time, which could adversely affect our business operations and financial performance. Further, existing tax laws and regulations could be interpreted, modified, or applied adversely to us.
The unavailability, reduction or elimination of government and economic incentives and credits could have a material adverse effect on our business, prospects, financial condition, results of operations, and cash flows.
Any unavailability, reduction, or elimination of government and economic incentives and credits because of policy changes, or the reduced need for such incentives and credits due to the perceived success of nuclear energy or other reasons, may result in the diminished competitiveness of the alternative fuel and nuclear energy industry generally or our reactors, software and services in particular. Any of the foregoing could materially and adversely affect the growth of the alternative fuel automobile markets and our business, prospects, financial condition, results of operations, and cash flows.
While certain tax credits and other incentives for alternative energy production, alternative fuel, and nuclear energy have been available in the past, there is no guarantee these programs will be available in the future. Some of these tax credits and incentives require interpretations from government bodies and any changes could impact the applicability of these tax credits and incentives. Incentives provided by federal or state authorities may have predetermined expiration dates, may conclude once allocated funds are depleted, or could be reduced or discontinued due to changes in regulatory or legislative priorities. Consequently, the availability of tax credits or other government incentives and our ability and that of our customers and competitors to benefit from these credits and incentives remain uncertain at this time.
We may become involved in litigation that may materially adversely affect us.
From time to time, we may become involved in various legal proceedings relating to matters incidental to the ordinary course of our business, including intellectual property, commercial, product liability, employment, class action, whistleblower, personal injury, property damage, and other litigation and claims, and governmental and other regulatory investigations and proceedings. Such matters can be time-consuming, divert management’s attention and resources from the operation of our business and cause us to incur significant expenses or liability or require us to change our business practices. Because of the potential risks, expenses and uncertainties of litigation, from time to time, we may settle disputes, even where we believe that we have meritorious claims or defenses. Because litigation is inherently unpredictable, we cannot assure you that the results of any of these actions will not have a material adverse effect on our business.
Some of our customers’ projects will be regulated by U.S. federal energy regulators and may be materially adversely affected by changes in law, policy or regulation, or a failure to comply with laws or regulations.
Some of our customers’ projects in the U.S. will be subject to regulation at the federal level, by the Federal Energy Regulatory Commission (“FERC”). Under the Federal Power Act, FERC regulates the sale of electric energy at wholesale in interstate commerce and the transmission of electric energy in interstate commerce.
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FERC rate regulation will subject projects making wholesale sales of energy to a suite of regulations as well as certain risks, including the possibility that FERC may revoke or otherwise restrict their authorizations to make sales if FERC determines that such a company and its affiliates can exercise horizontal or vertical market power, create barriers to entry or engage in abusive affiliate transactions or market manipulation. Public utilities and their holding companies are subject to FERC reporting requirements that impose administrative burdens and that can expose a public utility to criminal and civil penalties for failure to comply with such requirements. Our projects will also likely be subject to certain reliability standards overseen by the North American Electric Reliability Corporation (“NERC”). Failure to comply with NERC reliability standards could lead to sanctions, including substantial monetary penalties.
Some of our customers’ U.S. projects will be located within organized bulk power markets administered by electric grid operators and some of our U.S. project companies will sell power in, and participate in, those markets. These electric grid operators each have their own rules set forth in FERC-approved tariffs and related documents that govern the functioning of the wholesale electricity markets they oversee, as well as interconnection to the transmission system. These electric grid operators, which operate like quasi-regulatory bodies, can impose new rules or adopt new interpretations thereof that can have a material adverse effect on our business. Electric grid operators market rules regularly change over time, and such changes may materially adversely affect our project companies’ ability to sell energy, capacity, and ancillary services at a beneficial price and materially adversely affect our business.
A failure to comply with U.S. energy laws or FERC, NERC or electric grid operator rules and regulations could have a material adverse effect on our customers, which could in turn have a material adverse effect on our business, including any existing or future financing arrangements.
Any actual or perceived failure to comply with new or existing laws, regulations and other requirements relating to the privacy, security and processing of Personal Information could adversely affect our business, results of operations, or financial condition.
In connection with running our business, we receive, store, use and otherwise process information that relates to individuals and/or constitutes “personal data,” “personal information,” “personally identifiable information,” or similar terms under applicable data privacy laws (collectively, “Personal Information”), including from and about actual and prospective customers. as well as our employees and business contacts. We therefore may be subject to laws, regulations and other requirements relating to the privacy, security and handling of Personal Information.
The application and interpretation of such laws, regulations, and other requirements are constantly evolving and are subject to change, creating a complex compliance environment. In some cases, these requirements may be either unclear in their interpretation and application or they may have inconsistent or conflicting requirements with each other. Further, there has been a substantial increase in legislative activity and regulatory focus on data privacy and security in the U.S. and elsewhere, including in relation to cybersecurity incidents.
It is possible that new laws, regulations and other requirements, or amendments to or changes in interpretations of existing laws, regulations and other requirements, may require us to incur significant costs, implement new processes, or change our handling of information and business operations. In addition, any failure or perceived failure by us to comply with laws, regulations and other requirements relating to the privacy, security and handling of information could result in legal claims or proceedings, regulatory investigations, or enforcement actions. We could incur significant costs in investigating and defending such claims and, if found liable, pay significant damages or fines or be required to make changes to our business. These proceedings and any subsequent adverse outcomes may subject us to significant negative publicity and an erosion of trust. If any of these events were to occur, our business, results of operations, and financial condition could be materially adversely affected.
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Risks Relating to X-energy’s Capital Resources
In order to fulfill our business plan, we will require additional funding. To the extent we require such additional investor funding in the future, such funding may be dilutive to our investors and no assurances can be provided as to terms of any such funding. Any such funding and the associated terms will be highly dependent upon market conditions and the progress of our business at the time we seek such funding. The terms of any financing that we pursue may be less favorable than previously anticipated and could become even less favorable depending on the amount of funds we may require.
Our business is capital intensive. We expect that significant additional capital will be needed in the future to continue our planned operations, including commercialization efforts, expanded research and development activities, investment in our customers’ projects, risk-sharing arrangements, and costs associated with operating as a public company. To raise capital, we may enter into financing arrangements that may be costly or impose certain restrictive covenants or otherwise restrict our ability to seek additional leverage or financing. We may also seek to sell common stock, convertible securities or other equity securities in one or more transactions at prices and in a manner we determine from time to time. If we sell common stock, convertible securities or other equity securities, investors may be materially diluted by subsequent sales. Such sales may also result in material dilution to our existing stockholders, and new investors could gain rights, preferences and privileges senior to the holders of our common stock. Any of the above events could significantly harm our business, prospects, financial condition and results of operations and cause the price of our common stock to decline.
Our corporate expenditures, including our corporate level outspend, are subject to numerous risks and uncertainties.
Our current and future operating expenses are uncertain and impacted by various factors outside of our control, including rising costs and other impacts of inflation, evolving regulatory requirements, raw material availability, global conflicts, global supply chain challenges and component manufacturing and testing uncertainties, among other factors. Accordingly, it is possible that our overall expenses and related outspend could be higher than the levels we currently estimate, and any increases could have a material adverse effect on our business, financial condition, operating results and future prospects.
We may experience a disproportionately higher impact from inflation and rising costs.
Inflation has resulted in, and may continue to result in, higher interest rates and capital costs, higher shipping costs, higher material costs, supply shortages, increased costs of labor and other similar effects. Although the impact of material cost, labor, or other inflationary or economically driven factors will impact the entire nuclear and energy transition industry (including renewable sources of electricity, like solar and wind), the relative impact may not be the same across the industry, and the particular effects within the industry will depend on a number of factors, including material use, design, structure of supply agreements, project management and others, which could result in significant changes to the competitiveness of our technology and our ability to sell Xe-100 reactors and our TRISO-X fuel, which could have a material adverse effect on our business, financial condition, operating results and future prospects.
We have a history of losses and may not achieve profitability in the future. We will need substantial additional capital to fund our operations. If we fail to obtain significant additional capital in connection with the consummation of this offering, we will be unable to sustain operations unless we are able to raise additional capital following this offering from additional funding sources.
We expect to continue to incur operating losses for the foreseeable future as we continue to expand and develop, and we will need additional capital from external sources. If we are unable to raise additional capital, we will have to significantly delay, scale back or discontinue one or more of our research and development programs. We may be required to cease operations or seek partners for our product candidates at an earlier stage than otherwise would be desirable and on terms that are less favorable than might otherwise be available. In the absence of additional capital, we may also be required to relinquish, license or otherwise dispose of rights to technologies, product candidates or products that we would otherwise seek to develop or commercialize on terms that are less favorable than might otherwise be available. If we are unable to secure
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additional capital, we may be required to take additional measures to reduce costs in order to conserve our cash in amounts sufficient to sustain operations and meet our obligations. These measures may significantly alter our business plan and could cause significant delays in the development of our product candidates.
Future indebtedness could expose us to risks that could adversely affect our business, financial condition, operating results and future prospects.
In the future, we may incur indebtedness. Future indebtedness could have significant negative consequences for our security holders, business, results of operations and financial condition by, among other things:
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increasing our vulnerability to adverse economic and industry conditions;
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limiting our ability to obtain additional financing;
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requiring the dedication of a substantial portion of our cash flow from operations to service our indebtedness, which will reduce the amount of cash available for other purposes;
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limiting our flexibility to plan for, or react to, changes in our business; and
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placing us at a possible competitive disadvantage with competitors that are less leveraged than us or have better access to capital.
Our business may not generate sufficient funds, and we may otherwise be unable to maintain sufficient cash reserves, to pay any additional indebtedness that we may incur. Any future indebtedness that we may incur may contain financial and other restrictive covenants that will limit our ability to operate our business, raise capital or make payments under our indebtedness. If we fail to comply with such covenants or to make payments under any of our indebtedness when due, then we would be in default under that indebtedness, which could, in turn, result in that indebtedness becoming immediately payable in full and cross-default or cross-acceleration under our other indebtedness and other liabilities.
Our actual operating results may differ significantly from our guidance.
From time to time, we may release guidance in our quarterly earnings releases, quarterly earnings conference calls, or otherwise once we are a public company, regarding our future performance that represents our management’s estimates as of the date of release. This guidance, which includes forward-looking statements, will be based on projections prepared by our management. These projections are not prepared with a view toward compliance with published guidelines of the American Institute of Certified Public Accountants, and neither our registered public accountants nor any other independent expert or outside party compiles or examines the projections. Accordingly, no such person expresses any opinion or any other form of assurance with respect to the projections.
Projections are based upon a number of assumptions and estimates that, while presented with numerical specificity, are inherently subject to significant business, economic, and competitive uncertainties and contingencies, many of which are beyond our control, such as the effects of inflation on our cost estimates and expectations, and are based upon specific assumptions with respect to future business decisions, some of which will change. Any material change to the assumptions or estimates underlying the projections management prepares, or any material overruns or other unexpected increase in costs, could have a material adverse effect on the projections and the guidance on which it is based. The rapidly evolving market in which we operate may make it difficult to evaluate our current business and our future prospects, including our ability to plan for and model future growth. We intend to state possible outcomes as high and low ranges which are intended to provide a sensitivity analysis as variables are changed. However, actual results will vary from our guidance and the variations may be material. The principal reason that we release guidance is to provide a basis for our management to discuss our business outlook as of the date of release with analysts and investors. We do not accept any responsibility for any projections or reports published by any such persons. Investors are urged not to rely upon our guidance in making an investment decision regarding our common stock.
Any failure to successfully implement our operating strategy or the occurrence of any of the events or circumstances set forth in this “Risk Factors” section could result in our actual operating results being different from our guidance, and the differences may be adverse and material.
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Our financial results may vary significantly from quarter to quarter.
We expect our revenue and operating results to vary from quarter to quarter. We may incur significant operating expenses during the startup and early stages of large contracts and may not be able to recognize corresponding revenue in that same quarter. We may also incur additional expenses when contracts are terminated or expire and are not renewed.
Payments due to us from our customers may be delayed due to billing cycles or as a result of failures of government budgets to gain congressional and administration approval in a timely manner. The U.S. government’s fiscal year ends September 30. If a federal budget for the next federal fiscal year has not been approved by that date in each year, our customers may have to suspend engagements that we are working on until a budget has been approved. Any such suspensions may reduce our revenue in the fourth quarter of the federal fiscal year or the first quarter of the subsequent federal fiscal year.
Additional factors that may cause our financial results to fluctuate from quarter to quarter include those addressed elsewhere in this “Risk Factors” section and the following factors, among others:
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the terms of customer contracts that affect the timing of revenue recognition;
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variability in demand for our services and solutions;
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commencement, completion or termination of contracts during any particular quarter;
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timing of shipments and product deliveries;
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timing of award or performance incentive fee notices;
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timing of significant bid and proposal costs;
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the costs of remediating unknown defects, errors or performance problems of our product offerings;
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variable purchasing patterns under blanket purchase agreements and other indefinite delivery/ indefinite quantity contracts;
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restrictions on and delays related to the export of nuclear articles and services;
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costs related to government inquiries;
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strategic decisions by us or our competitors, such as acquisitions, divestitures, spin-offs and joint ventures;
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strategic investments or changes in business strategy;
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changes in the extent to which we use subcontractors;
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seasonal fluctuations in our staff utilization rates;
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changes in our effective tax rate, including changes in our judgment as to the necessity of the valuation allowance recorded against our deferred tax assets; and
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the length of sales cycles.
Changes in our accounting estimates and assumptions could negatively affect our financial position and results of operations.
We prepare our consolidated financial statements in accordance with U.S. GAAP. These accounting principles require us to make estimates and assumptions that affect the reported amounts of assets and liabilities and the disclosure of contingent assets and liabilities at the date of our financial statements. We are also required to make certain judgments that affect the reported amounts of revenues and expenses during each reporting period. We periodically evaluate our estimates and assumptions including, but not limited to, those relating to amortization and depreciation, estimates of costs to complete long-term contracts and the associated revenues, the valuation of profits interests, unit-based compensation, preferred units, warrants, exchanged debt, and liabilities measured at fair value. We base our estimates on historical experience and various assumptions that we believe to be reasonable based on specific circumstances. These assumptions and estimates involve the exercise of judgment and discretion, which may evolve over time in light of operational
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experience, regulatory direction, developments in accounting principles and other factors. Actual results could differ from these estimates as a result of changes in circumstances, assumptions, policies or developments in the business, which could materially affect our consolidated financial statements.
Risks Related to our Capital Structure
Our principal asset after the completion of this offering will be our interest in XERC, and, as a result, we will depend on distributions from XERC to pay our taxes and expenses (including payments under the Tax Receivable Agreement) and pay dividends. XERC’s ability to make such distributions may be subject to various limitations and restrictions.
Upon the consummation of this offering and the Transactions, we will be a holding company and will have no material assets other than our ownership of Common Units. As such, we will have no independent means of generating revenue or cash flow, and our ability to pay our taxes and operating expenses or declare and pay dividends in the future, if any, will be dependent upon the financial results and cash flows of XERC and distributions we receive from XERC. There can be no assurance XERC will generate sufficient cash flow to distribute funds to us or that applicable state law and contractual restrictions, including negative covenants in any applicable debt instruments, will permit such distributions. XERC is currently subject to debt instruments or other agreements that restrict its ability to make distributions to us, which may in turn affect XERC’s ability to pay distributions to us and thereby adversely affect our cash flows.
XERC will continue to be treated as a partnership for U.S. federal income tax purposes and, as such, generally will not be subject to any entity-level U.S. federal income tax. Instead, any taxable income of XERC will be allocated to holders of Common Units, including us. Accordingly, we will incur income taxes on our allocable share of any net taxable income of XERC. Under the terms of the XERC LLC Agreement, XERC will be obligated, subject to various limitations and restrictions, including with respect to our debt agreements, to make tax distributions to holders of Common Units, including us. In addition to tax expenses, we will also incur expenses related to our operations, including payments under the Tax Receivable Agreement, which we expect will be significant. See “Certain Relationships and Related Party Transactions — Tax Receivable Agreement.” We intend, as its managing member, to cause XERC to make cash distributions to the holders of Common Units in an amount sufficient to (i) fund all or part of their tax obligations in respect of taxable income allocated to them and (ii) cover our operating expenses, including payments under the Tax Receivable Agreement. However, XERC’s ability to make such distributions may be subject to various limitations and restrictions, such as restrictions on distributions that would either violate any contract or agreement to which XERC is then a party, including debt agreements, or any applicable law, or that would have the effect of rendering XERC insolvent. If we do not have sufficient funds to pay tax or other liabilities, or to fund our operations (including, if applicable, because of an acceleration of our obligations under the Tax Receivable Agreement), we may have to borrow funds, which could materially and adversely affect our liquidity and financial condition, and subject us to various restrictions imposed by any lenders of such funds. To the extent we are unable to make timely payments under the Tax Receivable Agreement for any reason, such payments generally will be deferred and will accrue interest until paid; provided, however, that nonpayment for a specified period may constitute a material breach of a material obligation under the Tax Receivable Agreement resulting in the acceleration of payments due under the Tax Receivable Agreement. See “Certain Relationships and Related Party Transactions — Tax Receivable Agreement.” In addition, if XERC does not have sufficient funds to make distributions, our ability to declare and pay cash dividends will also be restricted or impaired, although we do not anticipate declaring or paying any cash dividends on our Class A common stock in the foreseeable future. See “Risk Factors — Risks Related to the Offering and Ownership of our Class A common stock” and “Dividend Policy.”
Under the XERC LLC Agreement, we intend to cause XERC, from time to time, to make distributions in cash to the holders of Common Units (including us) in amounts sufficient to cover the taxes imposed on their allocable share of taxable income of XERC. As a result of (i) potential differences in the amount of net taxable income allocable to us and to the other holders of Common Units, (ii) the lower tax rate applicable to corporations as opposed to individuals, and (iii) certain tax benefits covered by, and payments under, the Tax Receivable Agreement, these tax distributions may be in amounts that exceed our tax liabilities. Our board of directors will determine the appropriate uses for any excess cash so accumulated, which may include, among other uses, the payment of obligations under the Tax Receivable Agreement and the payment of other
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expenses. We will have no obligation to distribute such cash (or other available cash) to our shareholders. No adjustments to the exchange ratio for Common Units and corresponding shares of Class A common stock will be made as a result of any cash dividend or distribution by us or any retention of cash by us. As a result, the holders of Common Units (other than us) may benefit from value, if any, attributable to such cash balances if they acquire shares of Class A common stock in exchange for their Common Units, notwithstanding that such holders may have participated previously as holders of Common Units in distributions that resulted in such excess cash balances to us. See “Description of Capital Stock.” To the extent we do not distribute such excess cash as dividends on our Class A common stock we may take other actions with respect to such excess cash, for example, holding such excess cash, or lending or contributing it (or a portion thereof) to XERC, which may result in shares of our Class A common stock increasing in value relative to the value of Common Units. Following a contribution of such excess cash to XERC we may make an adjustment to the outstanding number of Common Units held by holders of Common Units (other than us).
In addition, the tax distributions that XERC may be required to make may be substantial, and the amount of any additional tax distributions XERC is required to make likely will exceed the tax liabilities that would be owed by a corporate taxpayer similarly situated XERC. Funds used by XERC to satisfy its obligation to make tax distributions will not be available for reinvestment in our business, except to the extent we or certain other Continuing Equity Owners use any excess cash received to reinvest in XERC for additional Common Units.
Moreover, because cash available for additional tax distributions will be determined by taking into account the ability of XERC and its subsidiaries to take on additional borrowing, XERC may be required to increase its indebtedness in order to fund additional tax distributions. Such additional borrowing may adversely affect our results of operations, cash flows and financial position by, without limitation, limiting our ability to borrow in the future for other purposes, such as capital expenditures, and increasing our interest expense and leverage ratios.
The Tax Receivable Agreement with XERC and the TRA Holders requires us to make cash payments to the TRA Holders in respect of certain tax benefits to which we may become entitled, and we expect that such payments will be substantial.
In connection with the consummation of this offering, we will enter into a Tax Receivable Agreement with XERC and the TRA Holders. Under the Tax Receivable Agreement, we will be required to make cash payments to the TRA Holders equal to 85% of the tax benefits, if any, that we actually realize, or in certain circumstances are deemed to realize, as a result of (i) Basis Adjustments and (ii) Interest Deductions. We will be required to make such payments to the TRA Holders even if all of the TRA Holders were to exchange or redeem their remaining Common Units.
The payment obligations under the Tax Receivable Agreement are an obligation of the Company and not of XERC. We expect that the amount of the cash payments we will be required to make under the Tax Receivable Agreement will be substantial. Any payments made by us to the TRA Holders under the Tax Receivable Agreement will not be available for reinvestment in our business and will generally reduce the amount of overall cash flow that might have otherwise been available to us. To the extent that we are unable to make timely payments under the Tax Receivable Agreement for any reason, the unpaid amounts will be deferred and will accrue interest until paid by us; provided, however, that nonpayment for a specified period may constitute a material breach of a material obligation under the Tax Receivable Agreement resulting in the acceleration of payments due under the Tax Receivable Agreement. See “Certain Relationships and Related Party Transactions — Tax Receivable Agreement.” Furthermore, if we experience a change of control (as defined under the Tax Receivable Agreement), which includes certain mergers, asset sales, and other forms of business combinations, we would be obligated to make an immediate payment, and such payment may be significantly in advance of, and may materially exceed, the actual realization, if any, of the future tax benefits to which the payment relates. This payment obligation could (i) make us a less attractive target for an acquisition, particularly in the case of an acquirer that cannot use some or all of the tax benefits that are the subject of the Tax Receivable Agreement and (ii) result in holders of our Class A common stock receiving substantially less consideration in connection with a change of control transaction than they would receive in the absence of such obligation. Accordingly, the TRA Holders’ interests may conflict with those of the holders of our Class A common stock.
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Assuming no material changes in the relevant tax laws and that we earn sufficient taxable income to realize all tax benefits that are subject to the Tax Receivable Agreement, we expect that the tax savings associated with the purchase of Common Units in connection with this offering, together with future redemptions or exchanges of all remaining Common Units owned by the TRA Holders pursuant to the XERC LLC Agreement as described above, would aggregate to approximately $ million over years from the date of this offering based on the assumed initial public offering price of $ per share of our Class A common stock, which is the midpoint of the range set forth on the cover page of this prospectus, and assuming all redemptions or exchanges would occur immediately after the initial public offering for the remaining ownership of XERC not acquired by X-energy, Inc., which is assumed to occur on for purposes of the pro forma information presented herein and elsewhere in this prospectus. Under such scenario, assuming future payments are made on the date each relevant tax return is due, without extensions, we would be required to pay approximately 85% of such amount, or approximately $ million, over the -year period from the date of this offering, to the TRA Holders. The actual Basis Adjustments and the actual utilization of any resulting tax benefits, as well as the amount and timing of any payments under the Tax Receivable Agreement, will vary depending upon a number of factors including: the timing of redemptions by the TRA Holders; the price of shares of our Class A common stock at the time of the exchange; the extent to which such exchanges are taxable; the amount of gain recognized by such TRA Holders; the amount and timing of the taxable income allocated to us or otherwise generated by us in the future; the portion of our payments under the Tax Receivable Agreement constituting imputed interest; and the federal and state tax rates then applicable.
Our organizational structure, including the Tax Receivable Agreement, confers certain benefits upon the Continuing Equity Owners that will not benefit holders of our Class A common stock to the same extent that it will benefit the Continuing Equity Owners.
Our organizational structure, including the Tax Receivable Agreement, confers certain benefits upon the Continuing Equity Owners that will not benefit the holders of our Class A common stock to the same extent that it will benefit the Continuing Equity Owners. We will enter into the Tax Receivable Agreement with XERC and the TRA Holders in connection with the completion of this offering and the Transactions, which will provide for the payment by us to the TRA Holders of 85% of the amount of tax benefits, if any, that we actually realize, or in some circumstances are deemed to realize, as a result of (i) Basis Adjustments and (ii) Interest Deductions. See “Certain Relationships and Related Party Transactions — Tax Receivable Agreement.” Although we will retain 15% of the amount of such tax benefits, this and other aspects of our organizational structure may adversely impact the future trading market for our Class A common stock.
In certain cases, payments under the Tax Receivable Agreement to the TRA Holders may be accelerated or significantly exceed any actual benefits we realize in respect of the tax attributes subject to the Tax Receivable Agreement.
The Tax Receivable Agreement will generally apply to each of our taxable years, beginning with the first taxable year ending after the consummation of the Transactions. There is no maximum term for the Tax Receivable Agreement. However, the Tax Receivable Agreement will provide that if (i) we materially breach any of our material obligations under the Tax Receivable Agreement, (ii) certain mergers, asset sales, other forms of business combinations or other changes of control occur after the consummation of this offering, or (iii) we elect an early termination of the Tax Receivable Agreement, then our obligations, or our successor’s obligations, under the Tax Receivable Agreement to make payments will be determined based on certain assumptions, including an assumption that we will have sufficient taxable income to fully utilize all potential future tax benefits that are subject to the Tax Receivable Agreement.
As a result of the foregoing, we would be required to make an immediate cash payment equal to the present value of the anticipated future tax benefits that are the subject of the Tax Receivable Agreement, based on certain assumptions, which payment may be made significantly in advance of the actual realization, if any, of such future tax benefits. Such cash payment to the TRA Holders could be greater than the specified percentage of any actual benefits we ultimately realize in respect of the tax benefits that are subject to the Tax Receivable Agreement. In these situations, our obligations under the Tax Receivable Agreement could have a substantial negative impact on our liquidity and could have the effect of delaying, deferring, or preventing certain mergers, asset sales, other forms of business combinations or other changes of control. For
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example, should we elect to terminate the Tax Receivable Agreement immediately following this offering, assuming no material changes in the relevant tax laws or tax rates and that we earn sufficient taxable income to realize all potential tax benefits that are subject to the Tax Receivable Agreement, we estimate that the aggregate of termination payments would be approximately $ million (at a discount rate of SOFR plus 100 basis points) based on the assumed initial public offering price of $ per share of our Class A common stock, which is the midpoint of the range set forth on the cover page of this prospectus, and assuming SOFR (as defined in the Tax Receivable Agreement) were to be . There can be no assurance that we will be able to fund or finance our obligations under the Tax Receivable Agreement. We may need to incur debt to finance payments under the Tax Receivable Agreement to the extent our cash resources are insufficient to meet our obligations under the Tax Receivable Agreement as a result of timing discrepancies or otherwise.
We will not be reimbursed for any payments made to the TRA Holders under the Tax Receivable Agreement in the event that any tax benefits are disallowed.
Payments under the Tax Receivable Agreement will be based on the tax reporting positions that we determine, and the Internal Revenue Service (“IRS”), or another tax authority, may challenge all or part of the Basis Adjustments or other tax benefits we claim, as well as other related tax positions we take, and a court could sustain such challenge. If the outcome of any such challenge would reasonably be expected to materially and adversely affect the rights and obligations of TRA Holders under the Tax Receivable Agreement, then we will not be permitted to settle such challenge without the consent (not to be unreasonably withheld or delayed) of the TRA Holders. The interests of the TRA Holders in any such challenge may differ from or conflict with our interests and your interests, and the TRA Holders may exercise their consent rights relating to any such challenge in a manner adverse to our interests and your interests. We will not be reimbursed for any cash payments previously made to the TRA Holders under the Tax Receivable Agreement in the event that any tax benefits initially claimed by us and for which payment has been made to a TRA Holder are subsequently challenged by a taxing authority and are ultimately disallowed. Instead, any excess cash payments made by us to a TRA Holder will be netted against future cash payments, if any, that we might otherwise be required to make to such TRA Holder, under the terms of the Tax Receivable Agreement. However, we might not determine whether we have effectively made an excess cash payment to a TRA Holder for a number of years following the initial time of such payment. Moreover, the excess cash payments we made previously under the Tax Receivable Agreement could be greater than the amount of future cash payments against which we would otherwise be permitted to net such excess. The applicable U.S. federal income tax rules for determining applicable tax benefits we may claim are complex and factual in nature, and there can be no assurance that the IRS or a court will agree with our tax reporting positions. As a result, payments could be made under the Tax Receivable Agreement significantly in excess of any actual cash tax savings that we realize in respect of the tax attributes with respect to a TRA Holder that are the subject of the Tax Receivable Agreement.
The acceleration of payments under the Tax Receivable Agreement in the case of certain changes of control may impair our ability to consummate change of control transactions or negatively impact the value received by owners of our Class A common stock.
The Tax Receivable Agreement will provide that upon certain mergers, asset sales or other forms of business combination or certain other changes of control, the Company’s (or its successor’s) obligations with respect to the Tax Receivable Agreement would be based on certain assumptions, including that we (or our successor) would have sufficient taxable income to fully utilize the benefits arising from the increased tax deductions and tax basis and other benefits covered by the Tax Receivable Agreement. Consequently, it is possible, in these circumstances, that the actual cash tax savings realized by us may be significantly less than the corresponding tax benefit payments under the Tax Receivable Agreement. The Company’s accelerated payment obligations and/or assumptions adopted under the Tax Receivable Agreement in the case of a change of control may impair our ability to consummate a change of control transactions or negatively impact the value received by owners of our Class A common stock in a change of control transaction.
The Continuing Equity Owners, including the X-energy Founder and certain of their affiliates, may have conflicting interests with holders of shares of our Class A common stock.
Immediately following this offering and application of the net proceeds therefrom, the X-energy Founder and certain of their affiliates will beneficially own approximately % of the combined voting power of our
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Class A common stock or Class B common stock (or approximately % if the underwriters exercise in full their option to purchase additional shares of Class A common stock). Each share of Class A common stock entitles the holder to one vote per share and each share of Class B common stock entitles the holder to one vote per share on all matters on which shareholders are entitled to vote generally. For a description of our multi-class structure, see “Description of Capital Stock.”
In addition, immediately following this offering and application of the net proceeds therefrom, the Continuing Equity Owners, including the X-energy Founder and certain of their affiliates, will own approximately % of the Common Units (or approximately % if the underwriters exercise in full their option to purchase additional shares of Class A common stock). Because they hold their ownership interest in our business directly in XERC, rather than through the Company, the Continuing Equity Owners, including the X-energy Founder and certain of their affiliates, may have conflicting interests with holders of shares of our Class A common stock. For example, if XERC makes distributions to the Company, the non-managing members of XERC will also be entitled to receive such distributions pro rata in accordance with their ownership of Common Units and their preferences as to the timing and amount of any such distributions may differ from those of our public shareholders. The Continuing Equity Owners, including the X-energy Founder and certain of their affiliates, may also have different tax positions from us that could influence their decisions regarding whether and when to dispose of assets, especially in light of the existence of the Tax Receivable Agreement that we entered into in connection with this offering with XERC and the TRA Holders, whether and when to incur new or refinance existing indebtedness and whether and when the Company should terminate the Tax Receivable Agreement and accelerate its obligations thereunder. In addition, the structuring of future transactions may take into consideration our pre-IPO owners’ tax or other considerations even where no similar benefit would accrue to us. See “Certain Relationships and Related Party Transactions — Tax Receivable Agreement.”
Our shares of Class B common stock will not have economic rights. Immediately following the consummation of this offering, all of our Class B common stock will be held by certain Continuing Equity Owners, and certain of their affiliates.
Changes in tax laws and unanticipated tax liabilities could adversely affect our effective income tax rate and profitability.
We are subject to income taxes in the U.S. Our effective income tax rate and profitability could be adversely affected in the future by several factors, including changes in tax laws, regulations, administrative guidance or interpretations at the federal, state, or international level and changes in the valuation of deferred tax assets and liabilities.
On July 4, 2025, the President signed into law the OBBBA, a sweeping tax and spending law that makes permanent many provisions of the 2017 Tax Cuts and Jobs Act (the “TCJA”), while introducing new tax policies and restructuring others. While certain provisions may reduce our tax liability, such as modifications to corporate tax rates, deductions, credits, treatment of foreign income, and expensing rules, others may introduce new complexity and audit risk. We will continue to monitor the potential impact of the OBBBA. Because tax laws are dynamic and often retroactive or uncertain in interpretation, projected tax liabilities may differ significantly from eventual obligations. The net impact remains uncertain, and misapplication of the new rules could lead to materially adverse outcomes.
We regularly assess all of these tax-related matters to determine the adequacy of its tax provision. If current tax strategies are ineffective or not in compliance with domestic and international tax laws, our financial position, operating results, and cash flows could be adversely affected.
Risks Related to the Offering and Ownership of our Class A common stock
There has been no prior public market for our Class A common stock, the stock price of our Class A common stock may be volatile or may decline regardless of our operating performance, and you may not be able to resell your shares at or above the initial public offering price.
There has been no public market for our Class A common stock prior to this offering. The initial public offering price for our Class A common stock was determined through negotiations between us and the
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underwriters and may vary from the market price of our Class A common stock following this offering. The market prices of the securities of newly public companies such as us, particularly in the nuclear industry, have historically been highly volatile. The market price of our Class A common stock may fluctuate significantly in response to numerous factors, many of which are beyond our control, including:
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overall performance of the equity markets and the performance of technology companies in particular;
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variations in our operating results, cash flows, and other financial metrics and non-financial metrics, and how those results compare to analyst expectations;
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changes in the financial projections we may provide to the public or our failure to meet these projections;
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failure of securities analysts to initiate or maintain coverage of us, changes in financial estimates by any securities analysts who follow our company, or our failure to meet these estimates or the expectations of investors;
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recruitment or departure of key personnel;
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the economy as a whole and market conditions in our industry;
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negative publicity related to problems in our manufacturing or the real or perceived quality of our products, as well as the failure to timely launch new products or services that gain market acceptance;
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rumors and market speculation involving us or other companies in our industry;
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announcements by us or our competitors of new products, services, features and content, significant technical innovations, acquisitions, strategic partnerships, joint ventures, or capital commitments;
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new laws or regulations or new interpretations of existing laws or regulations applicable to our business;
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lawsuits threatened or filed against us, litigation involving our industry, or both;
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developments or disputes concerning our or other parties’ products, services, or intellectual property rights;
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other events or factors, including those resulting from war, incidents of terrorism, or responses to these events;
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the expiration of contractual lock-up or market standoff agreements; and
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sales of shares of our Class A common stock by us or our stockholders.
In addition, the stock markets have experienced extreme price and volume fluctuations that have affected and continue to affect the market prices of equity securities of many companies. Stock prices of many companies have fluctuated in a manner unrelated or disproportionate to the operating performance of those companies. In the past, stockholders have instituted securities class action litigation following periods of market volatility. If we were to become involved in securities litigation, it could subject us to substantial costs, divert resources and the attention of management from our business, and adversely affect our business.
Sales, directly or indirectly, of a substantial amount of our Class A common stock in the public markets by our existing security holders may cause the price of our Class A common stock to decline.
Sales of a substantial number of shares of our Class A common stock into the public market, particularly sales by our directors, executive officers, and principal stockholders, or the perception that these sales might occur, could cause the market price of our Class A common stock to decline and could impair our ability to raise capital through the sale of additional equity securities. Many of our existing security holders have substantial unrecognized gains on the value of the equity they hold, and may take, or attempt to take, steps to sell, directly or indirectly, their shares or otherwise secure, or limit the risk to, the value of their unrecognized gains on those shares.
All of the shares of Class A common stock sold in this offering will be freely tradable without restrictions or further registration under the Securities Act except that any shares held by our affiliates, as defined in Rule 144 under the Securities Act, would only be able to be sold in compliance with Rule 144 and any applicable lock-up agreements described below.
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In connection with this offering, subject to certain customary exceptions, we, all of our directors and executive officers, and substantially all of the holders of the Common Units, have entered into market standoff agreements with us or lock-up agreements with the underwriters that prohibit them from selling, contracting to sell, granting any option for the sale of, transferring, or otherwise disposing of any shares of common stock, stock options, or any security or instrument related to common stock or stock options without the permission of J.P. Morgan Securities LLC and on behalf of the underwriters for a period of days from the date of this prospectus, subject to early termination as described below. See “Underwriting.”
Holders of our outstanding shares of Class A common stock and securities convertible into or exercisable or exchangeable for shares of our Class A common stock are subject to restrictions on their ability to sell or transfer their equity either prior to the pricing of this offering or from the pricing of this offering through the date that is days after the date of this prospectus. We refer to such period as the “lock-up period”. Pursuant to the lock-up agreements with the underwriters, if (1) at least 120 days have elapsed since the date of this prospectus, (2) we have publicly released our earnings results for the quarterly period during which this offering occurred, and (3) such lock-up period is scheduled to end during or within five trading days prior to a broadly applicable period during which trading in our securities would not be permitted under our insider trading policy, or a blackout period, such lock-up period will end ten trading days prior to the commencement of such blackout period. We and the underwriters may release certain stockholders from the market standoff agreements or lock-up agreements prior to the end of the lock-up period. Record holders of our securities are typically the parties to the lock-up agreements with the underwriters and to the market standoff agreements with us referred to above, while holders of beneficial interests in our shares who are also not holders in respect of such shares are not typically subject to any such agreements or other similar restrictions. Accordingly, we believe that holders of beneficial interests who are not holders and are not bound by market standoff or lock-up agreements could enter into transactions with respect to those beneficial interests that negatively impact our stock price. In addition, an equity holder who is neither subject to a market standoff agreement with us nor a lock-up agreement with the underwriters may be able to sell, short sell, transfer, hedge, pledge, or otherwise dispose of or attempt to sell, short sell, transfer, hedge, pledge, or otherwise dispose of, their equity interests at any time after the closing of our initial public offering. Any such transaction described above involving shares of our Class A common stock, or any perception by the market that such transaction may occur, could cause our stock price to decline.
When the applicable lock-up and market standoff periods described above expire, we and our security holders subject to a lock-up agreement or market standoff agreement will be able to sell our shares in the public market. In addition, J.P. Morgan Securities LLC and , on behalf of the underwriters, may, in their sole discretion, release all or some portion of the shares subject to lock-up agreements prior to the expiration of the lock-up period. Sales of a substantial number of such shares upon expiration of the lock-up and market standoff agreements, or the perception that such sales may occur, or early release of these agreements, could cause our market price to fall or make it more difficult for you to sell your Class A common stock at a time and price that you deem appropriate.
We may also issue our shares of common stock or securities convertible into shares of our common stock from time to time in connection with a financing, acquisition, investment, or otherwise. Any further issuance could result in substantial dilution to our existing stockholders and cause the market price of our Class A common stock to decline.
If securities or industry analysts do not publish research, or publish inaccurate or unfavorable research, about our business, the price of our Class A common stock and trading volume could decline.
The trading market for our Class A common stock will depend in part on the research and reports that securities or industry analysts publish about us or our business, our market, and our competitors. We do not have any control over these analysts. If few securities analysts commence coverage of us, or if industry analysts cease coverage of us, the trading price for our Class A common stock would be negatively affected. If one or more of the analysts who cover us downgrade our Class A common stock or publish inaccurate or unfavorable research about our business, our Class A common stock price would likely decline. If one or more of these analysts cease coverage of us or fail to publish reports on us regularly, demand for our Class A common stock could decrease, which might cause our Class A common stock price and trading volume to decline.
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We have identified a material weakness in our internal control over financial reporting. If our remediation of such material weakness is not effective, or if X-energy experiences additional material weaknesses or otherwise fails to design and maintain effective internal control over financial reporting in the future, X-energy’s ability to timely and accurately report its financial condition and results of operations or comply with applicable laws and regulations could be impaired, which may adversely affect investor confidence in X-energy and, as a result, the value of X-energy Class A common stock.
In connection with the preparation of our consolidated financial statements for the years ended December 31, 2024 and 2023, we identified a material weakness in our internal control over financial reporting. A material weakness is a deficiency, or combination of deficiencies, in internal control over financial reporting such that there is a reasonable possibility that a material misstatement of our annual or interim consolidated financial statements will not be prevented or detected on a timely basis.
For the years ended December 31, 2024 and 2023, the material weakness primarily relates to the following matter that is relevant to the preparation of our consolidated financial statements:
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we lacked a sufficient complement of accounting and financial reporting personnel to analyze and interpret complex technical agreements and related valuations and ensure we record and disclose transactions appropriately.
The material weakness described above, if not remediated, could result in a misstatement of one or more account balances or disclosures that would result in a material misstatement to the annual or interim consolidated financial statements that would not be prevented or detected.
In order to remediate this material weakness, we have taken and plan to take the following actions:
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continuing to hire additional, qualified accounting and finance personnel; and
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designing and implementing additional controls and processes that operate at an appropriate level of precision to ensure adequate review of highly complex technical agreements and valuations.
We cannot assure you that the measures we have taken to date, and that we are continuing to implement, will be sufficient to remediate the material weakness we have identified or to avoid the identification of additional material weaknesses in the future. If the steps we take do not remediate the material weakness in a timely manner, there could continue to be a reasonable possibility that this control deficiency or others could result in a material misstatement of our annual or interim consolidated financial statements that would not be prevented or detected on a timely basis.
The process of designing and implementing internal control over financial reporting required to comply with the disclosure and attestation requirements of Section 404 of the Sarbanes-Oxley Act will be time consuming and costly. If, during the evaluation and testing process we identify additional material weaknesses in our internal control over financial reporting or determine that the existing material weakness has not been remediated, our management will be unable to assert that our internal control over financial reporting is effective and our independent registered public accounting firm may conclude that there are material weaknesses with respect to our internal control over financial reporting. If we are unable to assert that our internal control over financial reporting is effective, or when required in the future, if our independent registered public accounting firm is unable to express an unqualified opinion as to the effectiveness of our internal control over financial reporting, investors may lose confidence in the accuracy and completeness of our financial reports, the market price of our common stock could be adversely affected and we could become subject to litigation or investigations by the stock exchange on which our securities are listed, the SEC, or other regulatory authorities, which could require additional financial and management resources.
An active, liquid trading market for X-energy’s securities may not develop, which may limit your ability to sell such securities.
Although we intend to apply to list the Class A common stock on the Nasdaq under the ticker symbol XE, an active trading market for the Class A common stock may never develop or be sustained following this offering. The initial valuation of $ per share may not be indicative of the market price of the Class A common stock that will prevail in the open market after this offering. A public trading market having the desirable characteristics of depth, liquidity and orderliness depends upon the existence of willing buyers and
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sellers at any given time, such existence being dependent upon the individual decisions of buyers and sellers over which neither we nor any market maker has control. The failure of an active and liquid trading market to develop and continue would likely have a material adverse effect on the value of the Class A common stock, and you may not be able to sell your Class A common stock at an attractive price or at all. An inactive market may also impair our ability to raise capital to continue to fund operations by issuing additional shares of Class A common stock.
We will have broad discretion in the use of the net proceeds we receive in this offering and may not use them effectively.
We will have broad discretion in the application of the net proceeds we receive in this offering, including for any of the purposes described in the section titled “Use of Proceeds,” and you will not have the opportunity as part of your investment decision to assess whether we are using the net proceeds appropriately. Because of the number and variability of factors that will determine our use of the net proceeds from this offering, their ultimate use may vary substantially from their currently intended use. If we do not use the net proceeds that we receive in this offering effectively, our business, financial condition, operating results, and prospects could be harmed, and the market price for our Class A common stock could decline. Pending their use, we may invest the net proceeds from this offering in short-term, investment-grade interest-bearing securities such as money market accounts, certificates of deposit, commercial paper, and guaranteed obligations of the U.S. government that may not generate a high yield to our stockholders. These investments may not yield a favorable return to our investors.
We do not intend to pay dividends on the common stock of X-energy for the foreseeable future.
We have never declared or paid any cash dividends on the common stock of X-energy and do not intend to pay any cash dividends in the foreseeable future. Additionally, our ability to pay dividends on our common stock is limited by the restrictions under the terms of our loan and security agreement. We anticipate that for the foreseeable future we will retain all of our future earnings for use in the development of our business and for general corporate purposes. Any determination to pay dividends in the future will be at the discretion of our board of directors. Holders of our Class B common stock do not have any economic rights or any right to receive dividends, or to receive a distribution upon a liquidation, dissolution or winding up X-Energy, Inc., with respect to their Class B common stock. Accordingly, investors must rely on sales of their Class A common stock after price appreciation, which may never occur, as the only way to realize any future gains on their investments.
X-energy will incur significant transaction and transition costs in connection with the registration of securities.
X-energy will have incurred and expects to continue to incur significant, nonrecurring costs in connection with consummating the initial public offering and operating as a public company. For example, we will be subject to the reporting requirements of the Exchange Act and will be required to comply with the applicable requirements of the Sarbanes-Oxley Act and the Dodd-Frank Wall Street Reform and Consumer Protection Act, as well as rules and regulations subsequently implemented by the SEC, including the establishment and maintenance of effective disclosure and financial controls, changes in corporate governance practices and required filing of annual, quarterly and current reports with respect to our business and operating results. These requirements will increase our legal and financial compliance costs and will make some activities more time-consuming and costly. In addition, our management and other personnel will need to divert attention from operational and other business matters to devote substantial time to these public company requirements. We will also need to hire additional accounting and financial staff with appropriate public company experience and technical accounting knowledge and will need to establish an internal audit function. We also expect that operating as a public company will make it more expensive for us to obtain director and officer liability insurance, and we may be required to accept reduced coverage or incur substantially higher costs to obtain coverage. This could also make it more difficult for us to attract and retain qualified people to serve on our board of directors, our board committees or as executive officers.
In addition, after we no longer qualify as an “emerging growth company,” as defined under the JOBS Act, we expect to incur additional management time and cost to comply with the more stringent reporting requirements applicable to companies that are deemed accelerated filers or large accelerated filers, including
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complying with the auditor attestation requirements of Section 404 of the Sarbanes-Oxley Act. We are just beginning the process of compiling the system and processing documentation needed to comply with such requirements. We may not be able to complete our evaluation, testing and any required remediation in a timely fashion. In that regard, we currently do not have an internal audit function, and we will need to hire or contract for additional accounting and financial staff with appropriate public company experience and technical accounting knowledge.
We cannot predict or estimate the amount of additional costs we may incur as a result of becoming a public company or the timing of such costs.
We are eligible to be treated as an emerging growth company, as defined in the Securities Act, and we cannot be certain if the reduced disclosure requirements applicable to emerging growth companies will make our Class A common stock less attractive to investors because we may rely on these reduced disclosure requirements.
We are eligible to be treated as an emerging growth company, as defined in Section 2(a) of the Securities Act, as modified by the JOBS Act. Under the JOBS Act, emerging growth companies can delay adopting new or revised financial accounting standards until such time as those standards apply to private companies. We intend to take advantage of this extended transition period under the JOBS Act for adopting new or revised financial accounting standards.
For as long as we continue to be an emerging growth company, we may also take advantage of certain exemptions from various reporting requirements that are applicable to other public companies that are not emerging growth companies, including presenting only limited selected financial data and not being required to comply with the auditor attestation requirements of Section 404 of the Sarbanes Oxley Act. As a result, our shareholders may not have access to certain information that they may deem important. We could be an emerging growth company for up to five years, although circumstances could cause us to lose that status earlier, including if our total annual revenue exceeds $1.235 billion, if we issue more than $1.0 billion in nonconvertible debt securities during any three-year period, or if before that time we are a “large accelerated filer” under U.S. securities laws. We cannot predict if investors will find our Class A common stock less attractive because we may rely on these exemptions. If some investors find our Class A common stock less attractive, as a result, there may be a less active trading market for our Class A common stock and our share price may be more volatile.
We will incur increased costs as a result of operating as a public company, and our management will be required to devote substantial time to new compliance initiatives and corporate governance practices.
As a public company, and particularly after we are no longer an emerging growth company, we will incur significant legal, accounting and other expenses that we did not incur as a private company. The Sarbanes-Oxley Act, the Dodd-Frank Wall Street Reform, the Consumer Protection Act, the listing requirements of and other applicable securities rules and regulations impose various requirements on public companies, including establishment and maintenance of effective disclosure and financial controls and corporate governance practices. Our management and other personnel will need to devote a substantial amount of time to these compliance initiatives. Moreover, these rules and regulations will increase our legal and financial compliance costs and will make some activities more time-consuming and costly. For example, these rules and regulations may make it more difficult and more expensive for us to obtain director and officer liability insurance and make it more difficult for us to attract and retain qualified members of our board of directors.
We are evaluating these rules and regulations and cannot predict or estimate the amount of additional costs we may incur or the timing of such costs. These rules and regulations are often subject to varying interpretations, in many cases due to their lack of specificity, and, as a result, their application in practice may evolve over time as new guidance is provided by regulatory and governing bodies. This could result in continuing uncertainty regarding compliance matters and higher costs necessitated by ongoing revisions to disclosure and governance practices.
Key members of our management team have limited experience managing a public company.
Many members of our management team have limited experience managing a publicly traded company, interacting with public company investors and complying with the increasingly complex laws pertaining to
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public companies. Our management team may not successfully or efficiently manage our transition to being a public company subject to significant regulatory oversight and reporting obligations under the federal securities laws and the continuous scrutiny of securities analysts and investors. These new obligations and constituents will require significant attention from our senior management and could divert their attention away from the day-to-day management of our business, which could adversely affect our business, financial condition, operating results and future prospects.
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CAUTIONARY NOTE REGARDING FORWARD-LOOKING STATEMENTS
This prospectus contains forward-looking statements. These forward-looking statements include, without limitation, statements relating to expectations for future financial performance, business strategies or expectations for X-energy’s business. These statements are based on the beliefs and assumptions of the management of X-energy. Although X-energy believes that their plans, intentions and expectations reflected in or suggested by these forward-looking statements are reasonable, X-energy cannot assure you that it will achieve or realize these plans, intentions or expectations. These statements constitute projections, forecasts and forward-looking statements, and are not guarantees of performance. Such statements can be identified by the fact that they do not relate strictly to historical or current facts. When used in this prospectus, words such as “anticipate,” “believe,” “can,” “continue,” “could,” “estimate,” “expect,” “forecast,” “intend,” “may,” “might,” “plan,” “possible,” “potential,” “predict,” “project,” “seek,” “should,” “strive,” “target,” “will,” “would” and similar expressions may identify forward-looking statements, but the absence of these words does not mean that a statement is not forward-looking.
Forward-looking statements in this prospectus and in any document incorporated by reference in this prospectus may include, for example, statements about X-energy, including:
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the ability to obtain and maintain the listing of the Class A common stock on the Nasdaq following this offering;
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the ability to raise financing in the future and to comply with restrictive covenants related to indebtedness;
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the future financial performance of X-energy;
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anticipated trends, growth rates, and challenges in our business and in the markets in which we operate;
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the expectations and estimates presented regarding certain illustrative unit economics, including expectations with respect to costs, revenue and sources of revenue, and gross margins;
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the anticipated timeline for the completion of the design and target delivery estimates of the Xe-100 under the ARDP;
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X-energy’s ability to maintain, protect, and enhance its intellectual property;
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X-energy’s ability to retain or recruit, or to effect changes required in, its officers, key employees or directors following this offering;
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X-energy’s ability to comply with laws and regulations applicable to its business; and
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expansion plans and opportunities.
These forward-looking statements are based on information available as of the date of this prospectus and X-energy’s management teams’ current expectations, forecasts and assumptions. They involve a number of judgments, known and unknown risks and uncertainties and other factors, many of which are outside the control X-energy and its directors, officers and affiliates. Accordingly, forward-looking statements should not be relied upon as representing X-energy’s management teams’ views as of any subsequent date. X-energy does not undertake any obligation to update, add or to otherwise correct any forward-looking statements contained in this prospectus to reflect events or circumstances after the date they were made, whether as a result of new information, future events, inaccuracies that become apparent after the date of this prospectus or otherwise, except as may be required under applicable securities laws.
You should not place undue reliance on these forward-looking statements in deciding how your vote should be cast or in voting your shares on the proposals set out in this prospectus. Should one or more of a number of known and unknown risks and uncertainties materialize, or should any of our assumptions prove incorrect, our actual results or performance may be materially different from those expressed or implied by these forward-looking statements. Some factors that could cause actual results to differ include, but are not limited to:
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changes in applicable laws or regulations;
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changes to applicable government policies, priorities, regulations, mandates and funding levels relating to X-energy’s business with government entities;
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the impact to X-energy and its potential customers from changes in interest rates or inflation and rising costs, including commodity and labor costs;
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changes to the appropriations or funding available under the ARDP, including any failure by the U.S. government to appropriate additional funding to the ARDP, either to complete the existing award or in light of increased project costs and inflationary pressures;
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construction delays affecting the initial deployment of the Xe-100 under the ARDP;
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the ability to raise sufficient capital to fund X-energy’s business plan, including limitations on the amount of capital raised in the initial public offering;
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the impact and potential extended duration of the current supply/demand imbalance in the market for high-assay low-enriched uranium;
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X-energy’s business with various governmental entities being subject to the policies, priorities, regulations, mandates and funding levels of such governmental entities and being negatively or positively impacted by any change to such policies, priorities, regulations, mandates and funding levels;
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X-energy’s and its commercial partners’ ability to obtain regulatory approvals necessary to deploy small modular reactors in the U.S. and abroad in a timely way, or at all;
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X-energy’s and its commercial partners’ ability to deliver cost-competitive electricity from X-energy’s small modular reactors and to deliver cost-competitive fuel for such reactors;
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the inclusion or exclusion of advanced nuclear technologies in regulatory schemes related to climate change and/or reductions in carbon emissions;
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costs related to the initial public offering;
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the ability to accurately assess costs associated with developing the Xe-100 and fuel fabrication facilities; and
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other risks and uncertainties indicated in this prospectus, including those set forth under the section of this prospectus entitled “Risk Factors” beginning on page 23.
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USE OF PROCEEDS
We estimate that we will receive net proceeds of approximately $ million (or approximately $ million, if the underwriters exercise in full their over-allotment option) from the sale of shares of our common stock in this offering, assuming an initial public offering price of $ per share, which is the midpoint of the estimated price range set forth on the cover page of this prospectus, and after deducting the underwriting discounts and commissions and estimated offering expenses payable by us. An increase (decrease) of 1,000,000 shares from the expected number of shares of common stock to be sold by us in this offering, assuming no change in the assumed initial offering price per share, would increase (decrease) our net proceeds from this offering by $ million. A $1.00 increase (decrease) in the assumed initial public offering price would increase (decrease) the net proceeds to us from this offering by $ million, assuming the number of shares of common stock offered by us, as set forth on the cover page of this prospectus, remains the same, and after deducting the underwriting discounts and commissions and estimated offering expenses payable by us. We intend to use the proceeds from this offering to purchase newly issued Common Units from XERC. In the event the underwriters exercise their option to purchase additional shares of Class A common stock, we intend to use any proceeds from such exercise to purchase newly issued Common Units from XERC. The foregoing purchases of Common Units will be at a price per unit equal to the initial public offering price per share of Class A common stock in this offering, less the estimated underwriting discounts and commissions. XERC currently intends to use the net proceeds it receives from this offering for working capital and other general corporate purposes, which may include research and development and sales and marketing activities, general and administrative matters, and capital expenditures, including spending necessary for supply chain and procurement activities. We may also use a portion of the proceeds for future growth projects. We will not receive any proceeds for the sale of shares of common stock by the selling stockholders.
78
DIVIDEND POLICY
We currently expect to retain all future earnings for use in the operation and expansion of our business and have no current plans to pay dividends on our common stock. Holders of our Class B common stock are not entitled to participate in any dividends (other than certain in-kind dividends) declared by our Board. The declaration, amount and payment of any future dividends will be at the sole discretion of our board of directors, and will depend on, among other things, general and economic conditions, our results of operations and financial condition, our available cash and current and anticipated cash needs, capital requirements, contractual, legal, tax and regulatory restrictions and implications on the payment of dividends by us to our stockholders or by our subsidiaries to us, including restrictions under our credit agreements and other indebtedness we may incur, and such other factors as our board of directors may deem relevant. If we elect to pay such dividends in the future, we may reduce or discontinue entirely the payment of such dividends at any time. X-Energy, Inc. is a holding company and its operations are conducted through its wholly owned subsidiaries. In the event that we do pay a dividend, we intend to cause our operating subsidiaries to make distributions to us in an amount sufficient to cover such dividend. Any additional financing arrangement we enter into in the future may include restrictive covenants that limit our subsidiaries’ ability to pay dividends to us. In addition, Delaware law may impose requirements that may restrict our ability to pay dividends to holders of our common stock.
Immediately following this offering, we will be a holding company, and our principal asset will be the Common Units we purchase from XERC. If we decide to pay a dividend in the future, we would need to cause XERC to make distributions to us in an amount sufficient to cover such dividend. If XERC makes such distributions to us, the other holders of Common Units will be entitled to receive pro rata distributions. See “Risk Factors — Risks Related to Our Capital Structure — Our principal asset after the completion of this offering will be our interest in XERC, and, as a result, we will depend on distributions from XERC to pay our taxes and expenses (including payments under the Tax Receivable Agreement) and pay dividends. XERC’s ability to make such distributions may be subject to various limitations and restrictions.”
79
CAPITALIZATION
The following table sets forth the cash and cash equivalents and capitalization as of September 30, 2025 of X-Energy Reactor Company, LLC on an actual basis and of X-Energy, Inc. on a pro forma basis to reflect:
•
the Transactions; and
•
the sale of shares of our common stock offered by us in this offering at an assumed initial public offering price of $ per share, which is the midpoint of the estimated price range set forth on the cover page of this prospectus, after deducting the underwriting discounts and commissions and estimated offering expenses payable by us, and the application of the net proceeds to us therefrom as described under “Use of Proceeds.”
You should read this table in conjunction with the information contained in “Use of Proceeds,” “Summary Historical and Pro Forma Financial Information of X-energy,” and “Management’s Discussion and Analysis of Financial Condition and Results of Operations of X-energy” as well as our audited consolidated financial statements and related notes and our unaudited condensed consolidated financial statements and related notes, each included elsewhere in this prospectus.
| | | |
As of September 30, 2025
|
| |||||||||||||||
| | | |
X-Energy Reactor
Company, LLC |
| |
X-Energy, Inc.
|
| |
X-Energy, Inc.
Pro Forma |
| |||||||||
| | | |
Actual
|
| |
Pro Forma
|
| |
as Adjusted
|
| |||||||||
|
Cash and cash equivalents
|
| | | $ | 426,815 | | | | | $ | | | | | $ | | | ||
|
Mezzanine Equity:
|
| | | | | | | | | | | | | | | | | | |
|
Class A Common Units
|
| | | | 1,800 | | | | | | | | | | | | | | |
|
Class B Common Units
|
| | | | 92,913 | | | | | | | | | | | | | | |
|
Series A Redeemable Convertible Preferred Units
|
| | | | 218,408 | | | | | | | | | | | | | | |
|
Series A-1 Redeemable Convertible Preferred Units
|
| | | | 21,477 | | | | | | | | | | | | | | |
|
Series B Redeemable Convertible Preferred Units
|
| | | | 101,382 | | | | | | | | | | | | | | |
|
Series C Redeemable Convertible Preferred Units
|
| | | | 265,797 | | | | | | | | | | | | | | |
|
Series C-1 Redeemable Convertible Preferred Units
|
| | | | 686,715 | | | | | | | | | | | | | | |
|
Series D Redeemable Convertible Preferred Units
|
| | | | — | | | | | | | | | | | | | | |
|
Total mezzanine equity
|
| | | | 1,388,492 | | | | | | | | | | | | | | |
| Members’ Deficit: | | | | | | | | | | | | | | | | | | | |
|
Class A common stock
|
| | | | — | | | | | | | | | | | | | | |
|
Class B common stock
|
| | | | — | | | | | | | | | | | | | | |
| Additional paid-in-capital | | | | | 8,888 | | | | | | | | | | | | | | |
|
Accumulated and other comprehensive income
|
| | | | 176 | | | | | | | | | | | | | | |
|
Accumulated deficit
|
| | | | (1,164,645) | | | | | | | | | | | | | | |
|
Total members’ deficit / stockholders’ equity (deficit) attributable to X-Energy, Inc.
|
| | | | (1,155,581) | | | | | | | | | | | | | | |
|
Non-controlling interest
|
| | | | — | | | | | | | | | | | | | | |
|
Total capitalization
|
| | | | 561,699 | | | | | | | | | | | | | | |
A $1.00 increase (decrease) in the assumed initial public offering price of $ per share of Class A common stock, which is the midpoint of the estimated price range set forth on the cover page of this prospectus, would increase (decrease) the net proceeds that we receive in this offering and each of additional paid-in capital, total stockholders’ equity and total capitalization by approximately $ , assuming the number of shares of Class A common stock offered by us remains the same as set forth on the cover page of this prospectus and after deducting the underwriting discounts and commissions and estimated offering expenses payable by us. An increase (decrease) of 1,000,000 shares in the expected number of shares of Class A
80
common stock to be sold by us in this offering, assuming no change in the assumed initial public offering price, would increase (decrease) our net proceeds from this offering and each of additional paid-in capital, total stockholders’ equity and total capitalization by approximately $ . The pro forma column reflects the issuance of shares of common stock of X-Energy, Inc. in connection with the contribution of X-Energy Reactor Company, LLC by its unitholders and related reorganization transactions and related cancellation of all outstanding members’ equity at X-Energy Reactor Company, LLC in connection with the offering.
The table above does not include:
•
shares of Class A common stock reserved for issuance upon redemption or exchange of Common Units that will be held by the Continuing Equity Owners on a one-for-one basis; and
•
shares of Class A common stock reserved for future issuance under the 2026 Plan, which will become effective upon the effectiveness of the registration statement of which this prospectus forms a part (which number includes shares of our Class A common stock subject to restricted stock unit awards and stock options that will be granted to certain of our employees and directors pursuant to our 2026 Plan substantially concurrently with the consummation of this offering, based upon an assumed initial public offering price of $ per share (the midpoint of the estimated price range set forth on the cover page of this prospectus)).
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DILUTION
The Continuing Equity Owners will own Common Units after the Transactions. Because the Continuing Equity Owners do not own any Class A common stock or have any right to receive distributions from X-Energy, Inc., we have presented dilution in pro forma net tangible book value per share both before and after this offering assuming that all of the holders of Common Units (other than X-Energy, Inc.) had their Common Units redeemed or exchanged for newly issued shares of Class A common stock on a one-for-one basis (rather than for cash) and the transfer to the Company and cancellation for no consideration of all of their shares of Class B common stock common stock (which are not entitled to receive distributions or dividends, whether cash or stock from X-Energy, Inc.) in order to more meaningfully present the dilutive impact on the investors in this offering. We refer to the assumed redemption or exchange of all Common Units for shares of Class A common stock as described in the previous sentence as the Assumed Redemption.
Dilution is the amount by which the offering price paid by the investors of the Class A common stock in this offering exceeds the pro forma net tangible book value per share of Class A common stock after the offering. XERC’s pro forma net tangible book value (deficit) as of prior to this offering and after giving effect to the other Transactions, and the Assumed Redemption was $ million. Pro forma net tangible book value per share prior to this offering is determined by subtracting our total liabilities from the total book value of our tangible assets and dividing the difference by the number of shares of Class A common stock deemed to be outstanding after giving effect to the Assumed Redemption.
If you invest in our common stock in this offering, your ownership interest in us will be diluted to the extent of the difference between the initial public offering price per share of our common stock and the pro forma net tangible book value (deficit) per share of our common stock after giving effect to this offering. Dilution results from the fact that the per share offering price of the common stock is substantially in excess of the pro forma net tangible book value per share attributable to our existing owners.
Our pro forma net tangible book value (deficit) as of was approximately $ million, or $ per share of our common stock. We calculate pro forma net tangible value (deficit) per share by taking the amount of our total tangible assets, reduced by the amount of our total liabilities, and then dividing that amount by the total number of shares of common stock outstanding on a pro forma basis giving effect to the Reorganization Transactions.
After giving effect to (i) our sale of shares of common stock in this offering at an assumed initial public offering price of $ per share, which is the midpoint of the estimated price range set forth on the cover page of this prospectus, and (ii) the use of proceeds therefrom, after deducting the underwriting discounts and commissions and estimated offering expenses payable by us, our pro forma net tangible book value (deficit) as of would have been $ million, or $ per share of our common stock. This amount represents an immediate increase in pro forma net tangible book value (deficit) of $ per share of common stock to our existing owners and an immediate and substantial dilution in pro forma net tangible book value (deficit) of $ per share of common stock to new investors purchasing shares in this offering.
The following table illustrates this dilution on a per share of common stock basis assuming the underwriters do not exercise their option to purchase additional shares of common stock:
| |
Assumed initial public offering price per share of common stock
|
| | | $ | | | |
| |
Pro forma net tangible book value (deficit) per share of common stock as of
|
| | | | | | |
| |
Increase in pro forma net tangible book value per share of common stock attributable to investors in this offering
|
| | | | | | |
| |
Pro forma net tangible book value (deficit) per share of common stock after giving effect to this offering
|
| | | | | | |
| |
Dilution in pro forma net tangible book value per share of common stock to investors in this offering
|
| | | $ | | | |
Dilution is determined by subtracting pro forma net tangible book value (deficit) per share of common stock after the offering from the initial public offering price per share of common stock.
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Each $1.00 increase or decrease in the assumed initial public offering price per share of common stock would increase or decrease, as applicable, the pro forma net tangible book value by $ per share and the dilution to new investors in the offering by $ per share, assuming that the number of shares offered in this offering, as set forth on the cover page of this prospectus, remains the same. The pro forma information discussed above is for illustrative purposes only. Our net tangible book value (deficit) following the completion of the offering is subject to adjustment based on the actual offering price of our common stock and other terms of this offering determined at pricing.
The following table summarizes, on the same pro forma basis as of , the total number of shares of common stock purchased from us, the total cash consideration paid to us and the average price per share of common stock paid by our existing owners and by new investors purchasing shares of common stock in this offering.
| | | |
Shares Purchased
|
| |
Total Consideration
|
| |
Average Price
Per Share |
| ||||||||||||||||||
| | | |
Number
|
| |
Percent
|
| |
Amount
|
| |
Percent
|
| |||||||||||||||
| | | |
(in thousands)
|
| ||||||||||||||||||||||||
|
Existing owners
|
| | | | | | | % | | | | | $ | | | | | | % | | | | | $ | | | ||
|
New investors in this offering
|
| | | | | | | | | | | | | | | | | | | | | | | | | | | |
|
Total
|
| | | | | | | % | | | | | $ | | | | | | % | | | | | $ | | | ||
If the underwriters were to exercise in full their option to purchase additional shares of our common stock from us, the percentage of shares of our common stock held by existing owners as of would be %, the percentage of Class A common stock held by the Continuing Equity Owners would decrease to approximately % of the total number of shares of our Class A common stock outstanding after this offering and the percentage of shares of our common stock held by new investors in this offering would be %.
83
UNAUDITED PRO FORMA CONDENSED CONSOLIDATED FINANCIAL INFORMATION
Defined terms included below will have the same meaning as terms defined and included elsewhere in this prospectus.
The unaudited pro forma condensed consolidated financial information has been prepared in accordance with Article 11 of Regulation S-X under the Securities Act, as amended. The unaudited pro forma condensed consolidated financial information is presented to provide relevant information necessary for an understanding of X-energy upon consummation of the Company’s initial public offering after giving pro forma effect to the following (collectively, the “pro forma events”):
•
the Series D equity issuance in November 2025, as described in the subsequent event footnote to the Company’s historical financial statements as of and for the nine months ended September 30, 2025, which is presented below within Other Material Adjustments;
•
the Reorganization Transactions;
•
the impacts associated with the Tax Receivable Agreement, as described under “Certain Relationships and Related Party Transactions — Tax Receivable Agreement;” and
•
this offering and the application of the estimated net proceeds from this offering as described under “Use of Proceeds.”
The unaudited pro forma condensed consolidated balance sheet as of September 30, 2025 gives effect to the pro forma events as if they had been consummated on September 30, 2025.
The unaudited pro forma condensed consolidated statement of operations for the nine months ended September 30, 2025 and the unaudited pro forma condensed consolidated statement of operations for the year ended December 31, 2024 give effect to the pro forma events as if they had been consummated on January 1, 2024, the beginning of the earliest period presented.
We have derived the unaudited pro forma condensed consolidated balance sheet and the unaudited pro forma condensed consolidated statements of operations from our unaudited condensed consolidated financial statements as of and for the nine months ended September 30, 2025 and our audited consolidated financial statements for the year ended December 31, 2024, which are included elsewhere in this prospectus. The foregoing historical financial statements have been prepared in accordance with GAAP.
Except as otherwise indicated, the unaudited pro forma condensed consolidated financial information presented assumes no exercise by the underwriters of their over-allotment option to purchase additional shares.
As a public company, we will be implementing additional procedures and processes for the purpose of addressing the standards and requirements applicable to public companies. We expect to incur additional annual expenses related to these additional procedures and processes and, among other things, additional directors’ and officers’ liability insurance, director fees, additional expenses associated with complying with the reporting requirements of the SEC, transfer agent fees, costs relating to additional accounting, legal, and administrative personnel, increased auditing, tax, and legal fees, stock exchange listing fees, and other public company expenses. We have not included any pro forma adjustments relating to these costs in the information below.
The pro forma adjustments are based on available information and upon assumptions that management believes are reasonable in order to reflect, on a pro forma basis, the effect of the pro forma events on our historical financial information. The adjustments are described in the notes to the unaudited pro forma condensed consolidated balance sheet and the unaudited pro forma condensed consolidated statements of operations. The unaudited pro forma condensed consolidated financial information is presented for illustrative purposes only and do not purport to represent the results of operations or the financial position that would actually have occurred had the pro forma events been consummated on the dates assumed or to project the Company’s results of operations or financial position for any future date or period.
The unaudited pro forma condensed consolidated financial information should also be read together with “Basis of Presentation — Organizational Structure,” “Capitalization,” “Management’s Discussion and
84
Analysis of Financial Condition and Results of Operations of X-energy,” and our financial statements and accompanying notes included elsewhere in this prospectus.
Offering
The Company is offering shares of common stock in this offering at an assumed initial public offering price of $ per share, which is the midpoint of the estimated offering price range set forth on the cover page of this prospectus.
Reorganization Transactions
Reorganization Transactions refer to the organizational transactions immediately before the Offering by which (a) X-energy will become a holding company and the sole managing member of XERC; (b) Management LLC will contribute all of its Common Units of XERC to X-energy in exchange for an equal number of shares of X-energy Class A common, (c) each of the X-Energy Holdings, IBX Company Opportunity Fund 1, LP, IBX Company Opportunity Fund 2, LP, IBX Opportunity GP, Inc., X-energy KG Parent, LLC and GM Enterprises will contribute a portion of their respective Common Units of XERC to X-energy in exchange for an equal number of shares of X-energy Class A common stock; and (d) X-energy will issue Class B common stock to the Continuing Equity Owners in exchange for a nominal cash contribution made by such Continuing Equity Owners, resulting in a combined company organized in an Up-C structure, in which substantially all of the assets and the business of the company will be held by XERC, as more fully described elsewhere in this prospectus.
Upon closing, certain Original Equity Holders will sell their X-energy Class A stock, which will not result in proceeds to the Company, and the XERC Common Units owned by the Continuing Equity Owners will be considered noncontrolling interests in the consolidated financial statements of X-energy. Following the consummation of this offering, Continuing Equity Owners may redeem their Common Units for cash or Class A stock on a one-for-one basis.
Tax Receivable Agreement
Upon closing, we will enter into a Tax Receivable Agreement with XERC and the TRA Holders. Pursuant to the Tax Receivable Agreement, we will generally be required to pay the TRA Holders 85% of the amount of the cash tax savings, if any, in U.S. federal, state, and local taxes that are based on, or measured with respect to, net income or profits, and any interest related thereto that we realize, or are deemed to realize, as a result of the tax attributes subject to the Tax Receivable Agreement, including:
•
tax basis adjustments, including X-Energy, Inc. resulting from (i) certain distributions (or deemed distributions) by XERC; (ii) redemptions or (iii) from taxable exchanges of Common Units (including any such adjustments resulting from certain payments made by the Company under the Tax Receivable Agreement) acquired by us from one of the TRA Holders pursuant to the terms of the XERC LLC Agreement; and
•
tax deductions in respect of portions of certain payments made under the Tax Receivable Agreement.
Due to the uncertainty as to the amount and timing of future exchanges of Common Units by the TRA Holders and as to the price of our Class A common stock at the time of any such exchanges, the unaudited pro forma condensed consolidated financial information does not assume that any Continuing Equity Owners have exchanged Common Units that would create an obligation under the Tax Receivable Agreement. Therefore, no increases in tax basis in XERC’s assets or other tax benefits that may be realized under the Tax Receivable Agreement have been reflected in the unaudited pro forma condensed consolidated financial information. Future exchanges will result in incremental tax attributes and potential cash tax savings for us. Depending on our assessment on realizability of such tax attributes, the arising Tax Receivable Agreement liability will be recorded at the exchange date against equity, or at a later point through income.
However, if the Continuing Equity Owners as TRA Holders were to exchange or sell us all of their Common Units, we would recognize an incremental deferred tax asset of approximately $ million and an incremental liability under the Tax Receivable Agreement of approximately $ million, assuming:
(i) all exchanges or purchases occurred on the same day; (ii) a price of $ per share; (iii) a constant corporate tax rate; (iv) that we will have sufficient taxable income to fully utilize the tax benefits; and (v) no
85
material changes in tax law. These amounts are estimates and have been prepared for illustrative purposes only. The actual amount of deferred tax assets and related liabilities that we will recognize will differ based on, among other things, the timing of the exchanges, the price per share of our Class A common stock at the time of the exchange, and the tax rates then in effect and certain change of control or early termination events occurring.
If we exercise our right to terminate the Tax Receivable Agreement or in the case of a change in control or a material breach of our obligations under the Tax Receivable Agreement, all obligations under the Tax Receivable Agreement will be accelerated and we will be required to make a payment to the TRA Holders in an amount equal to the present value of future payments under the Tax Receivable Agreement. This payment would be based on certain assumptions, including that we would have sufficient taxable income to fully utilize the benefits arising from the tax attributes subject to the Tax Receivable Agreement.
86
Unaudited Pro Forma Condensed Consolidated Balance Sheet
As of September 30, 2025
(in thousands)
As of September 30, 2025
(in thousands)
| | | |
X-Energy
Reactor Company, LLC |
| |
Other
Material Transactions |
| | | | | | | |
Reorganization
Transaction Adjustments |
| | | | | | | |
Subtotal
|
| |
Offering
Transaction Adjustments |
| | | | | | | |
X-energy, Inc.
Pro Forma |
| ||||||
|
ASSETS
|
| | | | | | | | | | | | | | | | | | | |
|
| | | | | | | |
|
| |
|
| | | | | | | |
|
|
| Current assets | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
|
Cash and cash equivalents
|
| | | | 426,815 | | | | | | 700,000 | | | | | | (A) | | | | | | | | | | | | | | | | | | | | | (E) | | | | | |
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | (F) | | | | | |
|
Accounts receivable
|
| | | | 29,410 | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
|
Unbilled receivables and contract assets
|
| | | | 26,697 | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
|
Prepaid and other current assets
|
| | | | 9,010 | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | (F) | | | | | |
|
Due from related parties
|
| | | | 4,818 | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
|
Total current assets
|
| | | | 496,750 | | | | | | 700,000 | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
|
Restricted cash
|
| | | | 3,687 | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
|
Property and equipment, net
|
| | | | 37,232 | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
|
Operating lease right-of-use-assets
|
| | | | 22,756 | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
|
Other long-term assets
|
| | | | 1,274 | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
|
Total assets
|
| | | | 561,699 | | | | | | 700,000 | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
|
LIABILITIES, MEZZANINE EQUITY, AND MEMBERS’ DEFICIT
|
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| Current liabilities: | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
|
Short-term borrowings
|
| | | | — | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
|
Accounts payable
|
| | | | 7,875 | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
|
Accrued liabilities
|
| | | | 40,356 | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
|
Due to related parties
|
| | | | 4,925 | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
|
Total current liabilities
|
| | | | 53,156 | | | | | | — | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
|
Long-term operating lease liabilities
|
| | | | 19,012 | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
|
Warrant liabilities
|
| | | | 256,620 | | | | | | | | | | | | | | | | | | | | | (C) | | | | | | | | | | | | | | | | | |
|
Total liabilities
|
| | | | 328,788 | | | | | | — | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| Mezzanine equity | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
|
Class A Common Units
|
| | | | 1,800 | | | | | | | | | | | | | | | | | | | | | (B) | | | | | | | | | | | | | | | | | |
|
Class B Common Units
|
| | | | 92,913 | | | | | | | | | | | | | | | | | | | | | (B) | | | | | | | | | | | | | | | | | |
|
Series A redeemable convertible preferred units
|
| | | | 218,408 | | | | | | | | | | | | | | | | | | | | | (B) | | | | | | | | | | | | | | | | | |
|
Series A-1 redeemable convertible preferred units
|
| | | | 21,477 | | | | | | | | | | | | | | | | | | | | | (B) | | | | | | | | | | | | | | | | | |
|
Series B redeemable convertible preferred units
|
| | | | 101,382 | | | | | | | | | | | | | | | | | | | | | (B) | | | | | | | | | | | | | | | | | |
|
Series C redeemable convertible preferred units
|
| | | | 265,797 | | | | | | | | | | | | | | | | | | | | | (B) | | | | | | | | | | | | | | | | | |
|
Series C-1 redeemable convertible preferred units
|
| | | | 686,715 | | | | | | | | | | | | | | | | | | | | | (B) | | | | | | | | | | | | | | | | | |
|
Series D redeemable convertible preferred units
|
| | | | — | | | | | | 700,000 | | | | | | (A) | | | | | | | | | (B) | | | | | | | | | | | | | | | | | |
|
Total mezzanine equity
|
| | |
|
1,388,492
|
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
|
Class A Common Stock
|
| | | | — | | | | | | | | | | | | | | | | | | | | | (B) | | | | | | | | | | | | (E) | | | | | |
|
Class B Common Stock
|
| | | | — | | | | | | | | | | | | | | | | | | | | | (B) | | | | | | | | | | | | | | | | | |
87
| | | |
X-Energy
Reactor Company, LLC |
| |
Other
Material Transactions |
| | | | |
Reorganization
Transaction Adjustments |
| | | | | | | |
Subtotal
|
| |
Offering
Transaction Adjustments |
| | | | | | | |
X-energy, Inc.
Pro Forma |
| ||||||||||||||||||
|
Accumulated deficit
|
| | | | (1,164,645) | | | | | | | | | | | | | | | | | | | | | (C) | | | | | | | | | | | | | | | | | | (F) | | | | | | | | |
|
Accumulated other comprehensive income
|
| | | | 176 | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
|
Additional paid-in capital
|
| | | | 8,888 | | | | | | | | | | | | | | | | | | | | | (B) | | | | | | | | | | | | | | | | | | (E) | | | | | | | | |
| | | | | | | | | | | | | | | | | | | | | | | | | | | (D) | | | | | | | | | | | | | | | | | | (F) | | | | | | | | |
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | (D) | | | | | | | | |
|
Members’ deficit / Total shareholders’ equity (deficit) attributable to X-energy
|
| | |
|
(1,155,581)
|
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | ||||
|
Noncontrolling Interest
|
| | |
|
—
|
| | | | | | | | | | | | | | | | | | | | (D) | | | | | | | | | | | | | | | | | | (D) | | | | | | — | | |
|
Total shareholders’ equity / members’ deficit
|
| | | | (1,155,581) | | | | | | 700,000 | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
|
Total liabilities and shareholders’ equity / members’ deficit
|
| | | | 561,699 | | | | | | 700,000 | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| | ||||||||||||||||||||||||||||||||||||||||||||||||||||
88
Unaudited Pro Forma Condensed Consolidated Statement of Operations
Nine Months Ended September 30, 2025
(in thousands)
Nine Months Ended September 30, 2025
(in thousands)
| | | |
X-Energy
Reactor Company, LLC |
| |
Reorganization
Transaction Adjustments |
| | | | | | | |
Offering
Transaction Adjustments |
| | | | | | | |
X-Energy, Inc.
Pro Forma |
| ||||||||||||
|
Services revenue
|
| | | $ | 60,411 | | | | | $ | | | | | | | | | | | $ | | | | | | | | | | | $ | | | |||
|
Grant income
|
| | | | 12,324 | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
|
Total revenues and grant income
|
| | | | 72,735 | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
|
Operating expenses
|
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
|
Direct costs
|
| | | | 103,679 | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
|
Selling, general and administrative
|
| | | | 77,451 | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
|
Research and development
|
| | | | 1,376 | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
|
Total operating expenses
|
| | | | 182,506 | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
|
Operating loss
|
| | | | (109,771) | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
|
Other income (expense)
|
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
|
Interest expense
|
| | | | (476) | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
|
Interest income
|
| | | | 14,824 | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
|
Other income (expense), net
|
| | | | (222,655) | | | | | | | | | | | | (BB) | | | | | | | | | | | | | | | | | | | | |
|
Total other income (expense), net
|
| | | | (208,307) | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
|
Net income/(loss)
|
| | | | (318,078) | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
|
Net income/(loss) attributable to noncontrolling interest
|
| | | | — | | | | | | | | | | | | (AA) | | | | | | | | | | | | (AA) | | | | | | | | |
|
Net income/(loss) attributable to common stockholders
|
| | | $ | (318,078) | | | | | $ | | | | | | | | | | | | $ | | | | | | | | | | | $ | | | ||
|
Net income/(loss) per share attributable to
common stockholders |
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | $ | | | |
|
Weighted average shares outstanding of Class A common stock – basic and
diluted |
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
89
Unaudited Pro Forma Condensed Consolidated Statement of Operations
Year Ended December 31, 2024
(in thousands)
Year Ended December 31, 2024
(in thousands)
| | | |
X-Energy
Reactor Company, LLC |
| |
Reorganization
Transaction Adjustments |
| | | | | | | |
Offering
Transaction Adjustments |
| | | | | | | |
X-Energy, Inc.
Pro Forma |
| ||||||||||||
|
Services revenue
|
| | | $ | 83,986 | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
|
Grant income
|
| | | | 36,166 | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
|
Total revenues and grant income
|
| | | | 120,152 | | | | | $ | | | | | | | | | | | $ | | | | | | | | | | | $ | | | |||
| Operating expenses | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
|
Direct costs
|
| | | | 130,115 | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
|
Selling, general and administrative
|
| | | | 111,887 | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
|
Research and development
|
| | | | 1,662 | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
|
Total operating expenses
|
| | | | 243,664 | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
|
Operating loss
|
| | | | (123,512) | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| Other income (expense) | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
|
Interest expense
|
| | | | (16,190) | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
|
Interest income
|
| | | | 2,833 | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
|
Other income (expense), net
|
| | | | 10,909 | | | | | | | | | | | | (BB) | | | | | | | | | | | | | | | | | | | | |
|
Total other income (expense), net
|
| | | | (2,448) | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
|
Net loss
|
| | | | (125,960) | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
|
Net loss attributable to noncontrolling
interest |
| | | | — | | | | | | | | | | | | (AA) | | | | | | | | | | | | (AA) | | | | | | | | |
|
Net loss attributable to common stockholders
|
| | | $ | (125,960) | | | | | $ | | | | | | | | | | | | $ | | | | | | | | | | | $ | | | ||
|
Net income/(loss) per share attributable to
common stockholders |
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | $ | | | |
|
Weighted average shares outstanding of Class A common stock – basic and
diluted |
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
90
Notes to Unaudited Pro Forma Condensed Consolidated Financial Information
Note 1 Basis of Presentation
The unaudited pro forma condensed consolidated financial information has been prepared in accordance with Article 11 of Regulation S-X and presents the pro forma financial condition and results of operations of the Company based upon the historical financial information after giving effect to the pro forma events and related adjustments set forth in the notes to the unaudited pro forma condensed consolidated financial information.
The unaudited pro forma condensed consolidated financial information does not reflect any management adjustments for expected effects of the pro forma events.
The unaudited pro forma condensed consolidated balance sheet as of September 30, 2025, gives effect to the pro forma events as if they had occurred on September 30, 2025. The unaudited pro forma condensed consolidated statement of operations for the nine months ended September 30, 2025 and the unaudited pro forma condensed consolidated statement of operations for the year ended December 31, 2024, give effect to the pro forma events as if they had occurred on January 1, 2024.
The unaudited pro forma condensed consolidated financial information does not give effect to any income tax benefit or expense associated with the pro forma adjustments due to the history of losses in the current and previous periods and full valuation allowance on our deferred tax assets.
Note 2 Adjustments to the Unaudited Pro Forma Condensed Consolidated Balance Sheet
The following adjustments were made related to the unaudited pro forma condensed consolidated balance sheet as of September 30, 2025:
A.
Reflects the issuance of 48.1 million shares of Series D preferred stock for cash proceeds of $700.0 million, which occurred in November 2025.
B.
Immediately preceding the closing, as part of the Reorganization Transactions, XERC’s legacy Series A redeemable convertible preferred units, Series A-1 redeemable convertible preferred units, Series B redeemable convertible preferred units, Series C redeemable convertible preferred units, and Series C-1 redeemable convertible preferred units will be converted into Class A common stock, equal to the number of Common Units retained by each, and reclassified as permanent equity.
As a result of the Reorganization Transactions, the operating agreement of XERC will be amended and restated to, among other things, modify XERC’s capital structure by reclassifying each of the outstanding units in XERC into a single class of LLC Units, the Common Units.
This adjustment further reflects the acquisition of a number of shares of Class B common stock by the Continuing Equity Holders, equal to the number of Common Units retained by each, for nominal consideration.
C.
Represents the elimination of XERC’s legacy warrants, which were subject to cashless exercise immediately prior to closing. The issuance of shares related to this instrument are reflected in adjustment (B).
D.
Immediately following closing, the economic interests held by the noncontrolling interest (comprising Common Units issued at closing to Continuing Equity Owners) will be approximately %. The following table shows the economic interest of XERC immediately following the offering:
| | | |
Units
|
| |
%
|
|
|
X-energy
|
| |
|
| |
|
|
|
Other Common Units
|
| | | | | | |
|
Total Common Units
|
| | | | | | |
91
E.
Reflects the net effect on cash of the receipt of offering proceeds to us of $ million, based on the sale by the Company of million shares of Class A common stock at an assumed initial public offering price of $ per share (the midpoint of the price range set forth on the cover of this prospectus), after deducting the estimated underwriting discounts and commissions.
F.
Reflects estimated transaction costs of $ million, including certain legal, accounting, and other related costs. Upon completion of the offering, deferred transaction costs of $ will be charged against the proceeds from the offering with a corresponding reduction to additional paid-in capital; and transaction costs of $ will be expensed as incurred based on the nature of the costs.
Note 3 Adjustments to the Unaudited Pro Forma Condensed Consolidated Statement of Operations
The following adjustments were made related to the unaudited pro forma condensed consolidated statements of operations for the nine months ended September 30, 2025 and for the year ended December 31, 2024:
AA.
Represents net income/(loss) attributable to the noncontrolling interest based on the ownership structure at closing, as noted at adjustment (D).
BB.
Represents the elimination of the income statement impact related to the change in fair value of XERC’s legacy warrants. The elimination of these warrants, which do not survive the offering, is reflected at adjustment (C).
Note 4 Pro Forma Income/Loss Per Share
Represents the pro forma income/(loss) per share calculated using the weighted average shares outstanding as a result of the pro forma events, assuming the shares were outstanding since January 1, 2024. As the pro forma events are being reflected as if they had occurred at the beginning of the periods presented, the calculation of weighted average shares outstanding for basic and diluted pro forma income/(loss) per share assumes that the shares issuable relating to the pro forma events have been outstanding for the entire periods presented.
| | | |
Nine Months
Ended September 30, 2025 |
| |
Year Ended
December 31, 2024 |
| ||||||
| Pro forma basic and diluted income/loss per share | | | | | | | | | | | | | |
| Numerator: | | | | | | | | | | | | | |
|
Pro forma net income/(loss)
|
| | |
$
|
|
| | | | $ | | | |
|
Less: Pro forma net income/(loss) attributable to noncontrolling interests
|
| | | | | | | | | | | | |
|
Pro forma net income/(loss) attributable to common stockholders – basic and diluted
|
| | |
$
|
|
| | | | $ | | | |
| Denominator: | | | | | | | | | | | | | |
|
Pro forma weighted average shares outstanding of Class A common stock – basic and diluted
|
| | | | | | | | | | | | |
|
Pro forma basic and diluted income/(loss) per share, Class A common stock(1)
|
| | |
$
|
|
| | | | $ | | | |
(1)
Pro forma basic and diluted income/(loss) per share of Class B common stock is not presented as these shares have no economic rights.
The computation of pro forma diluted loss per share does not assume conversion, exercise or contingent issuance of securities as their inclusion in the pro forma loss per share calculation would have been antidilutive.
92
MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS OF X-ENERGY
The following discussion and analysis of X-energy’s financial condition and results of operations should be read with X-energy’s audited consolidated financial statements and notes thereto and unaudited condensed consolidated financial statements and notes thereto included elsewhere in this prospectus. Certain of the information contained in this discussion and analysis or set forth elsewhere in this prospectus, including information with respect to plans and strategy for X-energy’s business, includes forward-looking statements that involve risks and uncertainties. As a result of many factors, including those factors set forth in the section “Risk Factors,” X-energy’s actual results could differ materially from the results described in or implied by the forward-looking statements contained in the following discussion and analysis. Refer to the section entitled “Risk Factors” to gain an understanding of the important factors that could cause actual results to differ materially from X-energy’s forward-looking statements. For more information, see the section entitled “Cautionary Note Regarding Forward-Looking Statements.”
Unless otherwise indicated or the context otherwise requires, references in this section to the “Company,” “we,” “us,” “X-energy,” or “our” refer to the business of XERC for the period prior to the initial offering and X-Energy, Inc. and its subsidiaries for all periods after the initial offering.
Overview of Our Business and History
X-energy is a leading designer of advanced nuclear reactor technology (commonly referred to as small modular reactors, “SMRs”) and manufacturer of advanced nuclear fuels. We believe these scalable, power generation technologies help satisfy historically unprecedented electricity demand growth, driven by the development of AI and associated data center infrastructure. Total demand for new electricity generation is expected to increase globally by 7,626 TWh from 2023 to 2030 and the challenges associated with meeting this demand have led policymakers and industry leaders to recognize nuclear energy, particularly advanced nuclear, as a key component to address this need.
Founded in 2009 by Dr. Kamal “Kam” Ghaffarian to bring clean, safe, secure and affordable technology to market, X-energy is seeking to redefine the energy industry through its flagship product, the Xe-100, an advanced small modular HTGR, in development for nearly a decade. The Xe-100 reactor is designed to generate 80 megawatts of electric power or 200 megawatts of thermal output (heat), or a combination thereof. This reactor technology builds on more than 50 years of research and development by the global nuclear industry and the operating experience of previous HTGRs including those at Peach Bottom in the U.S., and Dragon in the U.K. in the 1960s-1970s, and more recently with China’s ongoing deployments of HTGRs in the 21st century.
The Xe-100 has several technological attributes that we believe make it advantaged compared to other sources of baseload generation. These include advanced safety features, virtually no direct GHG emissions during generation, high thermal output, load-following capabilities and modularity, all of which allow X-energy to more specifically meet a customer’s power and/or industrial heat needs. X-energy’s simple Xe-100 design directly translates into simplicity of project delivery through reduced supply chain complexity and labor intensity during construction, which we believe will lead to lower cost and faster deployment timelines when compared with conventional nuclear energy sources. X-energy has optimized the deployment of its Xe-100 into a four-reactor format that outputs 320 MWe (or 800 MWt). By deploying four independent reactor modules instead of a single unit, this optimized four-reactor configuration inherently delivers the high levels of reliability and redundancy required for both AI and industrial heat applications.
X-energy’s reactors use a TRISO coated particle fuel in the form of a spherical ‘pebble’, called TRISO-X fuel. This pebble fuel consists of HALEU fuel kernels individually encapsulated in layers of silicon carbide and pyrolytic carbon, forming miniature containment systems that trap fission products. These particles are then embedded in a graphite matrix to make fuel pebbles that possess exceptional safety margins and compacts, enabling operations at very high temperatures. The HALEU fuel used in our TRISO-X pebble fuel is enriched to 15.5%, a higher energy density form than the less than 5% LEU fuel used in conventional nuclear reactors. Our TRISO-X fuel will be produced at our fuel fabrication facility in Oak Ridge, Tennessee. The first facility, known as TX-1, began construction in October 2024 and is expected to be completed by the first half of 2028. Upon completion, it is expected to be North America’s first purpose-built commercial advanced nuclear fuel
93
fabrication facility. The TX-1 facility will have sufficient production capacity to support the fuel needs of the first 11 Xe-100 reactors at steady state operations.
In addition to its technology leadership, X-energy has three high-quality customers in Dow, Amazon, and Centrica, who we expect will underpin the deployment of the initial fleets of Xe-100 reactors. Taken together, assuming each customer exercises its contingent rights in full, these three customers provide us with a more than 11 gigawatts electric (“GWe”), 144 reactor pipeline across the U.S. and the U.K. with advanced development efforts already underway on the first Dow project at its Seadrift Operations site in Texas and the first Amazon project in connection with Energy Northwest.
X-energy maintains a strong relationship with the DOE and in December 2020 was awarded an initial $1.2 billion project as part of its selection as one of two awardees in the ARDP, the most substantial federal commitment to deploying advanced nuclear technology. The cooperative agreement for the program, signed in March 2021, provides 50/50 cost share, allowing X-energy to finish the remaining design, licensing, commercialization and construction of its first-of-a-kind commercial advanced nuclear plant and commercial TRISO-X fuel fabrication facility, while benefiting from decades of nuclear experience and knowledge within the DOE.
Our organizational structure following the offering and the Reorganization Transactions is commonly referred to as an umbrella partnership-C corporation (or “Up-C”) structure. Pursuant to this structure, following this offering we will hold a number of XERC Common Units equal to the number of our issued and outstanding shares of Class A common stock, and holders of XERC Common Units (each, an “Common Unit holder”) (other than us) will hold a number of XERC Common Units equal to the number of our issued and outstanding shares of Class B common stock. The Up-C structure was selected in order to (i) provide our Continuing Equity Owners with an option to continue to hold their economic ownership interests in our business in “pass-through” form for U.S. federal income tax purposes through their ownership of XERC Common Units and (ii) potentially allow our Continuing Equity Owners and us to benefit from certain net cash tax savings that we might realize in the future, as more fully described in the subsection titled “Certain Relationships and Related Party Transactions — Tax Receivable Agreement.”
Key Milestones that Transformed Our Business
![[MISSING IMAGE: fc_milestones-4clr.jpg]](https://cdn.kscope.io/66e241b40ec9a8be53aefe262681fd00-fc_milestones-4clr.jpg)
•
2009: X-energy founded by Kam Ghaffarian to bring safe, secure, clean and affordable technologies to the global marketplace.
•
2010 – 2011: Early studies working with a small team of engineers and consultants on nuclear technologies.
94
•
2012 – 2014: Onboarding expertise on HTGRs from South Africa’s Pebble-bed Modular Reactor program: Dr. Martin van Staden and Dr. Eben Mulder.
•
2015 – 2016: Conducted multi-dimensional trade studies on market needs, reactor size, and fuel form to refine early reactor concepts.
•
2016: Initial development of TRISO-X pebble fuel at Oak Ridge Pilot Facility.
•
2017 – 2019: Conceptual design of the Xe-100 after years of research & development.
•
2018: NRC regulatory engagement commenced.
•
2018: First pebble produced on commercial-scale equipment in pilot fuel facility at Oak Ridge National Lab in Tennessee.
•
2019: J. Clay Sell appointed as CEO.
•
March 2020: X-energy initial selection by the DOD for Project Pele development of micro-reactor concept. Across three awards (2020: $14.3 million, 2021: $28.7 million, 2023: $17.5 million), X-energy received approximately $60.0 million from the DOD which eventually lead to commercialization of XENITH microreactor. As of the date of this prospectus, the period of performance for the XENITH microreactor has expired, but the period of performance for Project Pele remains active.
•
December 2020: Won initial $1.2 billion award under the DOE’s ARDP.
•
July 2022: Signed exclusive framework agreement with Ontario Power Generation for Xe-100 deployment in Canada. OPG also became an equity investor in this year.
•
May 2023: Announced Dow’s Seadrift, Texas site as location for Xe-100. Dow becomes customer for ARDP from the DOE.
•
June 2023: Signed JDA with Energy Northwest for up to 12 Xe-100s (960 Mw) in central Washington.
•
October 2024: Construction of TX-1 site in Oak Ridge, Tennessee commenced. Vertical construction began in September 2025.
•
October 2024: Announced engagement with Amazon for options to bring over 5 GWe of new power projects online by 2039. First Amazon project identified as Energy Northwest site.
•
May 2025: Construction permit application to NRC for Dow’s UCC Seadrift Xe-100 project docketed for 18 month review timeline after March 2025 submission.
•
September 2025: Centrica and X-energy sign JDA to deploy 6 GWe of new nuclear capacity in the U.K.
Our Business Model
We have an intellectual property-driven business model based on our reactor and fuel. We expect to derive revenues from technology licensing, services and fuel operations that span the development and operation of the reactors.
•
Reactors: The revenue stream from reactors includes technology fees for the use of our intellectual property of the Xe-100 technology. We will not own and operate the facilities themselves, which we believe significantly reduces the amount of capital needed to operate our business.
We anticipate offering site-specific engineering and site characterization, project planning, assembly coordination, construction support, regulatory support, procurement support and long-term services to customers. Utilizing our knowledge and expertise in licensing, construction, procurement and other processes, we plan to provide customers with a full suite of value-added services during development of the nuclear power facilities. At the same time, we expect to generate long-term recurring revenue from services such as the ongoing maintenance and operator training through the anticipated 60-year life of a facility.
•
Fuel: We intend to provide manufacturing services to customers, including producing an initial fuel load of both TRISO-X fuel and an LEU-based TRISO fuel at commissioning of a plant. We expect to generate additional long-term recurring revenue from our own proprietary TRISO-X fuel that is
95
required to refuel plants during the anticipated 60-year life of each facility. We expect to bear limited inventory risks related to uranium or enriched uranium fuel feedstock. We intend to provide only fabrication supply services for customers and assume limited risks associated with holding the uranium or enriched uranium fuel feedstock. Additionally, we will not have any responsibility for spent fuel management beyond the design of such facilities to adequately handle spent fuel during the life of the plant. During operations, spent fuel remains the responsibility of the plant operator. Thereafter, permanent spent fuel management remains the responsibility of the DOE.
Factors Affecting Our Performance
The growth and future success of our business depends on many factors. While each of these factors present significant opportunities for our business, they also pose important challenges that we must successfully address in order to sustain our growth, improve our results of operations and achieve and maintain our long-term profitability.
Our ability to commence and expand commercial operations
Our business model is dependent on our commencing and expanding commercial operations. We currently anticipate initial customer deliveries to achieve mechanical completion in the early 2030s, which we expect to take place 1-2 years ahead of commencement of operations. Commencement of nuclear construction for these projects is dependent upon finalizing and achieving design maturity, producing fuel for customers, and supporting our customers in pursuing necessary permits and licenses from the NRC. Our team of engineers, scientists, and other staff is highly motivated and committed to accomplishing these challenges. Failure to complete any one of these tasks in a timely manner could result in us being unable to begin production in the anticipated timeframe.
We are developing a global network of potential customers and supply chain partners that we expect will play an integral role in bringing our technology to market. In the near term, TRISO-X and its customers will depend on the U.S. government for access to HALEU given the current inability to access global markets. The government and commercial enrichers are developing enrichment capabilities for future supplies. Additionally, the imposition of tariffs and impacts of inflation on raw materials or supplied components for our reactors could have a material adverse effect on our operations. Management has considered the potential economic impact of these tariffs as they relate to our suppliers and raw material needs, and believes our timeline to expand commercial operations will soften the impact these tariffs may have to the overall cost of our reactors. To the extent the U.S. government restricts our access to HALEU or otherwise fails to obtain sufficient HALEU for our needs, our ability to commence and expand commercial operations may be significantly impaired.
We have three publicly announced customers in (1) Dow, (2) Amazon, both of whom have made an equity investment in X-energy and (3) Centrica. As of the date of this prospectus, we also have a growing pipeline of customer opportunities across both power generation and industrial heat use cases across multiple geographies. We believe this growing pipeline of announced and potential customers is a demonstration of the increased market interest in, and provides external validation for, our products.
Widespread acceptance of nuclear power as an emissions-free energy source
Our growth and future success are dependent on public support for nuclear power in the U.S. and other countries where we intend to market and sell our technology, including Canada, the U.K. and certain countries in Europe and Asia, among others. Electricity demand is accelerating globally with the IEA estimating electricity consumption to grow by more than 25% from approximately 30,000 TWh in 2023 to approximately 37,000 TWh by 2030. In the U.S., electricity demand is currently driven by data center buildout from cloud computing providers, industrial growth and reshoring of manufacturing, and broader electrification (e.g., electric vehicle installed base). Given the importance of nuclear power to meeting data center expansion, Amazon, Google and Meta, among other companies, have signed a pledge to increase global nuclear capacity threefold by 2050. Industrial companies have historically relied on traditional fossil fuels such as natural gas to generate electricity and steam to power their facilities’ industrial processes. In order for our business model to succeed, we will depend on energy providers sourcing a larger percentage of energy from nuclear power facilities instead of sourcing energy from fossil fuel facilities. Additionally, the market for SMRs has not yet
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been established, as we are one of the pioneers in the industry. As we scale and continue to invest in the capabilities of our SMRs, we expect a growing number of jurisdictions throughout the U.S. and globally to adopt SMRs as an always-on, carbon emissions-free alternative to other energy sources. As nuclear power and SMRs, in particular, gain widespread acceptance, we expect the revenue we generate from sales of our SMRs to increase.
Our ability to manage operating expenses as a result of inflation and high development costs
We are a development and design stage company that is preparing its flagship product for market, with substantial governmental support and collaboration from a team of commercial partners. As we develop the Xe-100, TRISO-X fuel and other aspects of our business, we have been, and expect to continue to be, adversely affected by price increases from our suppliers and logistics partners as a result of inflation as well as other factors such as increased development, labor and overhead costs.
The Xe-100 and corresponding TRISO-X fuel are costly, complex and challenging to design and build. Sources of funding for the estimated cost include U.S. government funding, whether via the ARDP or other sources, and additional funding to be provided by X-energy’s designated partner under the ARDP (currently, Dow), although at present, Dow’s funding is released as project milestones are reached.
We continue to work with our commercial partners to seek opportunities for cost reduction for the ARDP. We nonetheless expect sustained and increased inflation in the future to directly impact our operating expenses, which, if left unmanaged, could ultimately impact expected gross margins across our business.
The capital expenditure for our reactors will not be included on our balance sheet. To the extent our reactors or the raw material needed to construct these reactors increase in price, our customers will bear the cost of these increases.
Our ability to obtain and maintain regulatory approvals at federal, state and local levels
Our capacity for continued growth and ability to achieve and maintain profitability depends in large part on our ability to operate effectively in multiple jurisdictions, including on an international, federal and local level. The federal government, along with each local jurisdiction (such as states, counties and townships) in which we operate, have unique regulatory dynamics. These include laws and regulations that can directly or indirectly affect our and our customers’ ability to operate, as well as matters related to real estate usage, environmental sustainability, employment and labor practices and community support. We believe that we have an industry-leading licensing team comprised of professionals who are in constant communication with the NRC and other regulators. Our success will depend on our licensing team’s ability to continue to obtain and maintain Regulatory Approvals in the ordinary course of business. The Dow project’s first Construction Permit Application (“CPA”) received an 18-month review schedule, and while we were able to interact in a collaborative and effective manner with the regulator, future projects may experience longer time horizons or difficulties related to agency interaction due to staffing changes or shortages. The CPA was submitted in March 2025, docketed in May 2025 and the review is expected to be complete by the end of year in 2026 with receipt of the CPA in the first quarter of 2027; however, any delay in this timeline or unforeseen challenges to this or other Regulatory Approvals for our or our customers could negatively impact our business.
While we operate in an industry that is subject to, and benefits from, safety and environmental regulations, there remain concerns that these regulation have generally become more stringent over time, particularly across developed markets. Regulations in our target markets include nuclear safety regulations, environmental assessments and export controls. As a company in a highly regulated industry, our margins could be particularly and adversely impacted by increasingly stringent regulatory developments or regulatory scrutiny. Regulations on nuclear energy, while historically similar between the U.S., the U.K., Canada and the European Union, where most of our production and sales are expected, are subject to unknown and unpredictable change that could impact our ability to meet projected sales or margins. Moreover, our and our customers’ ability to obtain Regulatory Approvals and comply with such approvals and nuclear regulatory requirements may affect our ability to market our technologies and receive approvals in other countries.
Our ability to capitalize on government expenditures and private sector investment in nuclear energy
Our future growth is largely dependent on our ability to continue to capitalize on government policy support and corporate investment in the nuclear energy industry.
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Congress has successfully reinvigorated the U.S. nuclear industry with a concentration on three main legislative priorities: (1) The initiation of the Advanced Reactor Demonstration Program, and its associated funding, to mitigate first-of-a-kind reactor cost and schedule risks; (2) Regulatory framework reform that is more aligned with the increased safety of advanced reactors through the Nuclear Energy Innovation and Modernization Act (NEIMA) in 2021 and the Accelerating Deployment of Versatile, Advanced Nuclear for Clean Energy Act (ADVANCE ACT) in 2024; (3) Enacting financial instruments such as Investor Tax Credits, Manufacturing Tax Credits and Production Tax Credits that are on a par with other clean energy tax credits, such as wind and solar, which included in the Inflation Reduction Act of 2022, and (4) Expanding and deploying federal credit support through the DOE’s Loan Programs Office, which provides loan guarantees and other credit assistance to catalyze first-of-a-kind and large-scale nuclear projects, fuel cycle facilities, life-extension and uprate initiatives, and other qualifying nuclear infrastructure, thereby lowering the cost of capital and accelerating commercial deployment.
X-energy was selected as a primary winner of the ARDP in 2020 and it is particularly critical to our success. The ARDP is a 50/50 cost-share between the DOE and the private sector to reduce the risks associated with building the first-of-a-kind reactor to the point of attracting follow-on customers both domestically and in the global marketplace. More specifically, through the ARDP, X-energy receives from the DOE 50% of the cost of designing the Xe-100. X-energy also receives 50% of the cost of TX-1, its first fuel fabrication facility. Finally, X-energy’s first customer to build a reactor, Dow, will receive 50% of the cost to build the first Xe-100, which it will do at its Seadrift site in Texas.
Congress has appropriated approximately $1.1 billion to X-energy’s ARDP. DOE’s ability to receive the not-yet-appropriated portion of the ARDP is subject to the political process, which is inherently unpredictable and highly competitive. As of September 30, 2025, we have received over $394 million in funding under the ARDP. The funding of government programs is dependent on budgetary limitations, congressional appropriations and administrative allotment of funds, all of which may be affected by changes in U.S. government policies resulting from various political developments. If political support for the prioritization of the development of nuclear energy decreases, including due to policy changes by the current administration and future administrations and changing congressional funding priorities, we may be unable to secure continued government funding under the ARDP, which would adversely affect our business, development timeline, and financial condition.
Our ability to expand our services offerings
We intend to offer customers a diversified suite of services throughout the life of a project / reactor, beginning approximately eight years prior to a plant’s commercial operation date. Our envisioned suite of services includes pre- and post-commercial operations date offerings, whereby we intend to provide customers with critical services related to the design, development, licensing, construction, fueling, operations and maintenance of the Xe-100. We expect that, as we refine our services offerings, first with Dow and the early Amazon and Centrica projects, the number of services we offer and the percentage of revenue we generate from our services offerings will grow. We anticipate that our services offerings will have high penetration rates across our future clients and will provide consistent, recurring revenues throughout the expected life of each reactor.
Our ability to obtain additional capital
We operate in a capital intensive industry and expect to continue to incur operating losses for the foreseeable future as we continue to expand and develop, and may need to raise additional capital in the future. If we are unable to raise additional capital when needed, we may have to delay, scale back or discontinue one or more of our lines of business. We may be required to cease operations or seek partners for our lines of business at an earlier stage than otherwise would be desirable and on terms that are less favorable than might otherwise be available. If we are unable to raise additional capital when needed, we may also be required to relinquish, license or otherwise dispose of rights to technologies or lines of business that we would otherwise seek to develop or commercialize on terms that are less favorable than might otherwise be available. If we are unable to secure additional capital when needed, we may be required to take additional measures to reduce costs in order to conserve our cash in amounts sufficient to sustain operations and meet our obligations. These
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measures may significantly alter our business plan and could cause significant delays in the development of our product candidates and ultimately our financial condition and ability to operate as a going concern.
Key Components of Results of Operations
Revenues and grant income
At present, our revenues and grant income are generally derived from contract services performed for the U.S. Government and commercial entities. In the future, we expect to generate revenue through technology fees for the use of the design of the Xe-100 technology, project planning, assembly coordination, construction support, regulatory support, procurement support, long-term services to customers and the supply of fuel and associated services. Our revenues are generally derived from cost-share agreements such as the ARDP provided by the U.S. government and research and development, product development, and fuel services provided to other government agencies and commercial entities. A majority of our contracts with the U.S. government are generally subject to FAR and are competitively priced based on estimated costs of providing the contractual goods or services.
Operating expenses
Direct costs
Direct costs include all costs directly attributable to the completion of contracts, such as direct labor, direct materials and subcontracting costs. Indirect costs are allocated to direct costs in the same manner as such costs are defined in disclosure statements under U.S. Government Cost Accounting Standards.
Selling, general and administrative
Selling, general and administrative expenses consist of human capital related expenses for employees involved in general corporate functions, including executive management and administration, accounting, finance, tax, legal, information technology, marketing and human resources; rent relating to our office space; professional fees; non-cash consideration issued to customers; and other general corporate costs.
Research and development
We conduct research and development activities related to the development and improvement of future technologies pertaining to nuclear reactor and fuel design engineering. The costs incurred for conducting the research and development primarily include labor, equipment and material.
Other income (expense)
Interest expense
Interest expense consists of interest paid and accrued on the Live Oak Credit Facility, Bank of New York Credit Facility, 2023 Bridge Loan, 2024 Convertible Note, and the 2024 Bridge Loan, as further discussed below, along with the amortization of deferred financing fees, costs and debt discounts.
Interest income
Interest income is related to our investment of excess cash in money market funds.
Other income (expense), net
Other income (expense), net consists of miscellaneous income and expenses such as the write-off of transaction costs due to termination of a Business Combination Agreement (“BCA”) with a publicly traded special purpose acquisition company (“SPAC”), and mark-to-market gains and losses on various instruments detailed in Note 13 — Fair Value Measurements of our audited consolidated financial statements and Note 12 — Fair Value Measurements of our unaudited condensed consolidated financial statements. Other income (expense), net also consists of the gain on conversion of C-1 Notes and C-2 Notes and related
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reclassification of other comprehensive income, losses on extinguishment of debt, gains and losses on foreign currency transactions, and other miscellaneous expenses.
Results of Operations
The following tables set forth our results of operations for the periods presented. The period-to-period comparison of financial results is not necessarily indicative of future results.
Comparison of Nine Months Ended September 30, 2025 and 2024
The following tables set forth our historical results for the periods indicated and the changes between periods:
| | | |
Nine Months Ended
September 30, |
| | | | | | | | | | | | | |||||||||
|
($ in thousands)
|
| |
2025
|
| |
2024
|
| |
$ Change
|
| |
% Change
|
| ||||||||||||
|
Services revenue
|
| | | $ | 60,411 | | | | | $ | 60,314 | | | | | $ | 97 | | | | | | 0 | | |
|
Grant income
|
| | | | 12,324 | | | | | | 25,674 | | | | | | (13,350) | | | | | | (52) | | |
|
Total revenues and grant income
|
| | |
|
72,735
|
| | | |
|
85,988
|
| | | |
|
(13,253)
|
| | | |
|
(15)
|
| |
| Operating expenses | | | | | | | | | | | | | | | | | | | | | | | | | |
|
Direct costs
|
| | | | 103,679 | | | | | | 98,926 | | | | | | 4,753 | | | | | | 5 | | |
|
Selling, general and administrative
|
| | | | 77,451 | | | | | | 40,523 | | | | | | 36,928 | | | | | | 91 | | |
|
Research and development
|
| | | | 1,376 | | | | | | 964 | | | | | | 412 | | | | | | 43 | | |
|
Total operating expenses
|
| | | | 182,506 | | | | | | 140,413 | | | | | | 42,093 | | | | | | 30% | | |
|
Operating loss
|
| | | | (109,771) | | | | | | (54,425) | | | | | | (55,346) | | | | | | 102% | | |
| Other income (expense) | | | | | | | | | | | | | | | | | | | | | | | | | |
|
Interest expense
|
| | | | (476) | | | | | | (15,917) | | | | | | 15,441 | | | | | | (97) | | |
|
Interest income
|
| | | | 14,824 | | | | | | — | | | | | | 14,824 | | | | | | 100 | | |
|
Other expense, net
|
| | | | (222,655) | | | | | | (8,377) | | | | | | (214,278) | | | | | | 2,558 | | |
|
Total other income (expense), net
|
| | | | (208,307) | | | | | | (24,294) | | | | | | (184,013) | | | | | | 757% | | |
|
Net loss
|
| | | $ | (318,078) | | | | | $ | (78,719) | | | | | $ | (239,359) | | | | | | 304% | | |
Revenues and grant income
Revenues and grant income decreased by $13.3 million or 15% for the nine months ended September 30, 2025, compared to the nine months ended September 30, 2024. The decrease is driven by a $12.4 million decrease in a service revenue contract with Dow to develop a small modular reactor at one of Dow’s U.S. Gulf Coast sites as a result of work slowing down after the submission of the application to the NRC in March 2025 and before the start of construction, a $3.6 million decrease in a service revenue contract with the DOD, and offset by a $1.9 million increase in a contract with Energy Northwest, which began services during the second quarter of 2024. Total revenues and grant income for the nine months ended September 30, 2025 and 2024 attributable to the ARDP contract with the DOE were $56 million and $55.1 million, respectively, of which $12.3 million and $25.7 million, respectively were recorded within grant income. There has been a $14.3 million increase in service revenue on the DOE contract and $13.3 million decrease in grant income on the DOE contract. The change in the DOE service revenue and grant income is due to the types of activities performed on the ARDP contract during fiscal year 2025.
Operating expenses
Direct costs
Direct costs increased by $4.8 million or 5% for the nine months ended September 30, 2025 compared to the nine months ended September 30, 2024, primarily due to an increase of $11.8 million in labor costs, which is driven by increase in employee headcount as the Company grows and an increase in bonuses . The increase
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is partially offset by a decrease of $5.6 million in subcontracting costs due to a shift in subcontractor activities from noncapitalizable development activities during the nine months ended 2024 to capitalizable activities related to the fuel facility beginning in the fourth quarter of 2024.
Selling, general and administrative
Selling, general and administrative expenses increased by $36.9 million or 91% for the nine months ended September 30, 2025 compared to the nine months ended September 30, 2024. This increase was primarily due to a $15.8 million increase in payroll related costs due to increase in employee headcount and a $10.0 million increase in unit-based compensation due to new grants made during the nine months ended September 30, 2025. The selling, general and administrative expenses were further increased by $7.0 million for contractor costs related to corporate projects, and a $4.4 million increase in bonuses.
Research and development
Research and development increased by $0.4 million or 43% for the nine months ended September 30, 2025 compared to the nine months ended September 30, 2024.
Other income (expense)
Interest expense
Interest expense decreased by $15.4 million or 97% for the nine months ended September 30, 2025 compared to the nine months ended September 30, 2024, due to settlement, maturity, redemption and conversion of the outstanding debt held by the Company which was effectuated in 2024.
Interest income
Interest income increased by $14.8 million or 100% for the nine months ended September 30, 2025 compared to the nine months ended September 30, 2024 due to the investment of excess cash into money market funds starting in the fourth quarter of 2024.
Other expense, net
Other expense, net, increased by $214.3 million or 2,558% for the nine months ended September 30, 2025 compared to the nine months ended September 30, 2024, primarily due to a remeasurement loss on warrant liabilities amounting to $203.9 million.
Comparison of Fiscal Years Ended December 31, 2024 and 2023
The following tables set forth our historical results for the periods indicated and the changes between periods:
| | | |
Year Ended December 31,
|
| | | | | | | | | | | | | |||||||||
|
($ in thousands)
|
| |
2024
|
| |
2023
|
| |
$ Change
|
| |
% Change
|
| ||||||||||||
|
Services revenue
|
| | | $ | 83,986 | | | | | $ | 121,877 | | | | | $ | (37,891) | | | | | | (31) | | |
|
Grant income.
|
| | | | 36,166 | | | | | | 11,165 | | | | | | 25,001 | | | | | | 224 | | |
|
Total revenues and grant income
|
| | |
|
120,152
|
| | | |
|
133,042
|
| | | |
|
(12,890)
|
| | | |
|
(10)
|
| |
| Operating expenses | | | | | | | | | | | | | | | | | | | | | | | | | |
|
Direct costs
|
| | | | 130,115 | | | | | | 199,586 | | | | | | (69,471) | | | | | | (35) | | |
|
Selling, general and administrative
|
| | | | 111,887 | | | | | | 68,693 | | | | | | 43,194 | | | | | | 63 | | |
|
Research and development
|
| | | | 1,662 | | | | | | 2,150 | | | | | | (488) | | | | | | (23) | | |
|
Total operating expenses
|
| | |
|
243,664
|
| | | |
|
270,429
|
| | | | | (26,765) | | | | |
|
(10)%
|
| |
|
Operating loss
|
| | | | | | | | | | | | | | | | | | | | | | | | |
|
Other income (expense)
|
| | |
|
(123,512)
|
| | | |
|
(137,387)
|
| | | |
|
13,875
|
| | | |
|
(10)%
|
| |
|
Interest expense
|
| | | | (16,190) | | | | | | (8,262) | | | | | | (7,928) | | | | | | 96 | | |
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| | | |
Year Ended December 31,
|
| | | | | | | | | | | | | |||||||||
|
($ in thousands)
|
| |
2024
|
| |
2023
|
| |
$ Change
|
| |
% Change
|
| ||||||||||||
|
Interest income
|
| | | | 2,833 | | | | | | 178 | | | | | | 2,655 | | | | | | 1,492 | | |
|
Other income (expense), net
|
| | | | 10,909 | | | | | | (85,749) | | | | | | 96,658 | | | | | | (113) | | |
|
Total other income (expense), net
|
| | | |
(2,448)
|
| | | | |
(93,833)
|
| | | | |
91,385
|
| | | | | (97)% | | |
|
Net loss
|
| | |
$
|
(125,960)
|
| | | |
$
|
(231,220)
|
| | | |
$
|
105,260
|
| | | | | (46)% | | |
| | |||||||||||||||||||||||||
Revenues and grant income
Revenues and grant income decreased by $12.9 million or 10% for fiscal 2024 compared to fiscal 2023. The decrease in revenue and grant income was primarily attributable to a $44.7 million decrease in revenue and grant income from contracts with the DOE, including the ARDP contract, which contemplates an aggregate of $1.2 billion in funding to support design, licensing, and commercialization of the Xe-100 and construction of the TX-1. The decrease in revenue on the ARDP contract in 2024 reflects a lower volume of work performed under the contract during the year due to a shift in the timing and scope of activities executed, compared to prior periods and the commencement of the facility construction activities on the contract that qualified for government grant accounting in fiscal 2024. Of this $44.7 million decrease in revenue and grant income from contracts with the DOE, $69.7 million of the decrease pertains to services revenue, which is offset by a $25.0 million increase in grant income. This decrease was partially offset by a $31.8 million increase in services revenue from other revenue contracts, primarily with commercial entities and the DOD. Out of the $31.8 million increase in revenues and grant income, $20.9 million of the increase is attributable to a contract and a joint development agreement with Dow to develop a small modular reactor at one of Dow’s U.S. Gulf Coast sites, and an additional $8.1 million is attributable to a contract with the DOD. Total revenues and grant income for the year ended December 31, 2024 and 2023 attributable to the ARDP contract with the DOE was $76.5 million and $121.9 million, respectively, of which $36.2 million and $11.2 million, respectively was recorded within grant income.
Operating expenses
Direct costs
Direct costs decreased by $69.5 million or 35% for fiscal 2024 compared to fiscal 2023 primarily due to a decrease of $65.6 million in subcontracting costs, which is driven by the reduction in activity on the ARDP cost-share contract during 2024, and a decrease of $3.1 million in labor costs.
Selling, general and administrative
Selling, general and administrative expenses increased by $43.2 million or 63% for fiscal 2024 compared to fiscal 2023. This increase was primarily due to the issuance of the 2024 Warrant to an investor and potential future customer. As the 2024 Warrant was issued for no additional consideration and the Company did not receive any rights or privileges from the holder that meet the definition of an asset, the issuance date fair value of the 2024 Warrant of $55.3 million was expensed upon its issuance. The increase was additionally due to a $2.9 million increase in bonuses in fiscal 2024 due to expenses for retention bonuses paid to employees in 2024 and 2025.
The increase in selling, general and administrative expenses was partially offset by an $8.9 million decrease in compensation and benefits, of which $4.2 million is due to a decrease in payroll related costs primarily due to a reduction in employee headcount, as a result of the reduction in force in the fourth quarter of fiscal 2023. The remaining $4.7 million of the decrease in compensation and benefits is related to a decrease in unit-based compensation, of which $2.6 million of the decrease pertains to the timing of vesting and $2.1 million of the decrease pertains to a grant to a former employee in 2023 that did not recur in 2024. The selling, general and administrative expenses were further decreased primarily due to a decrease of $2.7 million in professional fees related to the previous SPAC transaction that were incurred prior to the 2023 BCA termination, and a decrease of $1.0 million in contractor costs.
Research and development
Research and development decreased by $0.5 million or 23% for fiscal 2024 compared to fiscal 2023.
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Other income (expense)
Interest expense
Interest expense increased by $7.9 million or 96% for fiscal 2024 compared to fiscal 2023 primarily due to a $9.9 million increase in amortization of the debt discount, deferred financing fees and other costs. The increase in interest expense was further increased by a $1.0 million net increase in interest expense associated with the Live Oak Credit Facility, Bank of New York Credit Facility, and 2023 Bridge Loan, as described below. These increases in interest expense were partially offset by a $1.9 million decrease in credit support fees related to the Bank of New York Credit Facility, and a $1.3 million decrease in financing costs associated with the issuance of C-2 Notes in fiscal 2023 for which the fair value option was elected.
Interest income
Interest income increased by $2.7 million or 1,492% for fiscal 2024 compared to fiscal 2023 due to investment of excess cash into money market funds starting fiscal 2024.
Other income (expense), net
Other income (expense), net, was $10.9 million of income for fiscal 2024 compared to $85.7 million of expense for fiscal 2023, representing an increase in income of $96.7 million, or 113%. The other income increased by $107.2 million, which was primarily related to a $58.4 million write-off of transaction costs due to the BCA termination during 2023 that did not recur in 2024, an $18.6 million decrease in remeasurement loss on C-1 Notes and C-2 Notes, a $12.3 million increase in remeasurement gain on a liability instrument with a related party investor, a $12.6 million increase in remeasurement gain on derivative liabilities, and a $5.3 million increase in remeasurement gain on warrant liabilities. The other income was partially offset by $14.0 million which was primarily related to a $7.4 million increase in losses on the extinguishment of debt, and a $6.6 million increase in expense related to the reclassification of other comprehensive income into other expense upon the conversion of the C-1 and C-2 Notes into Series C Preferred Units.
Liquidity and Capital Resources
We assess our liquidity in terms of our ability to generate adequate amounts of cash to meet current and future needs. Our expected primary uses of cash on a short-term and long-term basis are for working capital requirements, capital expenditures, and other general corporate services. Our primary working capital requirements are for project execution activities including purchases of materials, subcontracted services and payroll which fluctuate during the year, driven primarily by the timing and extent of activities required on new and existing projects. Management expects that future operating losses and negative operating cash flows may increase from historical levels because of additional costs and expenses related to the development of our technology and the development of market and strategic relationships with other businesses. Consequently, our continued existence is dependent upon our ability to obtain additional capital to support our ongoing operations.
Historically, our primary source of funding to support our operations has been revenue and grant income from the ARDP contract, contributions and loans from members, loans from financial institutions as well as capital raises. During the nine months ended September 30, 2025, we successfully raised $53.4 million from issuance of Series C-1 Preferred Units. Subsequent to September 30, 2025, we successfully raised $700.0 million from the issuance of our Series D Preferred Units. During the fiscal year ended December 31, 2024, we successfully raised $626.5 million from issuance of Series C-1 Preferred Units. During the fiscal year ended December 31, 2023, we successfully raised aggregate of $107.3 million from issuance of Series C Preferred Units and C-2 Notes. While we have historically been successful in obtaining the capital necessary to support our operations, there is no assurance that we will be able to secure additional capital or other financing in the future.
We have had, and expect that we will continue to have, an ongoing need to raise additional capital from outside sources to fund our operations and expand our business. If we are unable to raise additional capital when desired, our business, financial condition, operating results and future prospects would be harmed, and we may not be able to construct the TX-1 fuel fabrication facility, support development of the Xe-100 plant,
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or conduct other research and development or project and fulfill our current business plan, and therefore, we may need to delay or abandon these and other projects. A successful transition to attaining profitable operations depends upon achieving a level of revenue and grant income adequate to support us.
We expect that working capital requirements will continue to be funded through a combination of cash on hand, funding awarded under the ARDP, further issuances of securities, and successful capital raises. In connection with our business plan, management anticipates additional increases in operating expenses and capital expenditures relating to the development and commercialization of the Xe-100. We intend to finance these expenses with further issuances of debt or equity securities. Thereafter, we expect we will need to raise additional capital and generate revenues and grant income to meet long-term operating requirements. If we raise additional funds through the issuance of equity or convertible debt securities, the percentage ownership of our equity holders could be significantly diluted, and these newly issued securities may have rights, preferences or privileges senior to those of existing equity holders. If we raise additional funds by obtaining loans from third parties, the terms of those financing arrangements may include negative covenants or other restrictions on our business that could impair our operating flexibility and also require us to incur interest expense.
Live Oak Credit Facility
On June 14, 2021, we and one of our subsidiaries entered into a credit agreement for a revolving credit facility (the “Live Oak Credit Facility”) with Live Oak Bank. The Live Oak Credit Facility provided for maximum borrowings of up to $15.0 million, subject to an asset-based borrowing base. The borrowing base was limited to a set percentage of eligible accounts, less reserves that may be established by the lender in the exercise of their reasonable credit judgment. Subject to certain conditions, the Live Oak Credit Facility, as amended prior to 2024, was set to expire on April 30, 2024, which was extended to October 31, 2024 through amendments entered into during 2024. In connection with the credit agreement, we incurred lender and third-party fees. Additionally, a commitment fee was accrued on any unused portion of the commitments under the Live Oak Credit Facility during the preceding three calendar month period. The commitment fee was 0.25% applied to the difference between the revolving commitment and the average daily outstanding balance for each quarter.
The obligations under the Live Oak Credit Facility were guaranteed by us and our wholly owned domestic subsidiaries. The obligations under the Live Oak Credit Facility were secured by a first priority security interest in substantially all of the equipment, accounts receivable, investment property and general intangibles and all proceeds and products thereof, as well as 100% of the common equity interests of the present and subsequently acquired domestic subsidiaries. The Live Oak Credit Facility was permitted to be voluntarily prepaid in whole, or in part, in each case without premium or penalty. We were also required to make mandatory prepayments when (a) the aggregate borrowings exceed the lesser of the (i) revolving commitment and (ii) the available borrowing base or (b) certain events of default have occurred and were continuing.
The Live Oak Credit Facility carried an interest rate based on a floating rate indexed to the Prime rate plus 1.0%, subject to a 4% floor. The average interest rate in effect under the Live Oak Credit Facility was 9.5% for the nine months ended September 30, 2024.
In accordance with the Live Oak Credit Facility’s stated terms, we settled the outstanding principal associated with the Live Oak Credit Facility in October 2024. On October 31, 2024, with no outstanding borrowings, the facility matured. On May 9, 2025, we reestablished the facility, with an expiration date of December 1, 2025. There have been no draws on the facility during the nine months ended September 30, 2025.
Bank of New York Credit Facility
On July 28, 2020, we executed a credit agreement with Pershing LLC, an affiliate of Bank of New York Mellon, in the form of a revolving credit facility (the “Bank of New York Credit Facility”), which was subject to the guarantee by Ghaffarian Enterprises, who represented a related party investor. In December 2023, we and Ghaffarian Enterprises entered into a Letter Agreement which stipulated Ghaffarian Enterprises would purchase $29.3 million of Series C Preferred Units and the proceeds were used to fully repay the Bank of New York Credit Facility, at which time the outstanding balance was approximately $31.0 million. In conjunction
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with our repayment, the collateral posted by Ghaffarian Enterprises was released and the reimbursement agreement and guaranty with Ghaffarian Enterprises terminated in December 2023. As such, the Bank of New York Credit Facility did not have an outstanding balance as of December 31, 2023.
During the year ended December 31, 2024, we entered into Credit Support Fee and Subrogation Agreements (the “2024 Credit Support Fee Agreements”) with GM Enterprises and Ghaffarian Enterprises, entities affiliated with an owner and member of our Board of Directors, which increased the availability under the Bank of New York Credit Facility to $20.0 million and extended the maturity of the credit support to March 26, 2025. In conjunction with the agreements, we agreed to pay GM Enterprises and Ghaffarian Enterprises, a monthly 12% credit support fee to be paid in-kind. Pursuant to the terms of the 2024 Credit Support Fee Agreements, we paid credit support fees of approximately $0.9 million and issued 562,483 Class B Common Units to GM Enterprises and Ghaffarian Enterprises. The Class B Common Units have the same rights as the Class B Profits Interests. In October 2024, we settled the outstanding principal and interest associated with the Bank of New York Credit Facility with a payment of $20.2 million, and the Credit Support Fee Agreements were terminated. As such, the Bank of New York Credit Facility did not have an outstanding balance as of September 30, 2025, and December 31, 2024.
Borrowings under the credit facility bear interest at the Federal Funds rate, subject to a 0.25% floor, plus a margin. For borrowings, the applicable rate margin is 0.90%. The proceeds of loans under the agreement are available for working capital needs, permitted acquisitions and other general corporate purposes. The average interest rate in effect under the revolving credit facility was 6.34% for the year ended December 31, 2024.
Apart from the C-2 Notes and the Bank of New York Credit Facility as disclosed above, we had the following debt outstanding during fiscal 2024 and 2023 which were settled, matured, redeemed or converted:
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Series C-1 Convertible Notes: During 2022, we issued a series of convertible promissory notes (“C-1 Notes”), in the aggregate principal amount of $57.4 million with an annual interest rate of 7.00%. Of the $57.4 million in principal, $37.4 million was due on March 31, 2024 and $20.0 million was due on October 7, 2024 to a related party. On December 5, 2023, in connection with the issuance of the Series C Preferred Units, a portion of the C-1 Notes equal to $37.4 million of principal automatically converted into 5,957,402 Series C Preferred Units at a discounted price per unit of $7.94. On March 29, 2024, the remaining $20.0 million principal outstanding of C-1 Notes was converted into 3,210,405 Series C Preferred Units.
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2023 Bridge Loan: On October 4, 2023, we entered into a credit agreement (the “2023 Bridge Loan”) with Ares Acquisition Holdings, LP, which was amended through various amendments. In connection with the amendments, the maturity date was extended to March 26, 2025. Subsequent to the initial October 4, 2023 issuance of $10.0 million, $14.2 million and $25.8 million was drawn during 2024 and 2023, respectively through amendments and delayed draws. On October 11, 2024, in accordance with the 2023 Bridge Loan’s stated terms, we paid the outstanding principal and interest on the 2023 Bridge Loan of $53.5 million, and the 2023 Bridge Loan was settled.
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2024 Convertible Note: On September 26, 2024, we entered into a convertible note with Amazon.com NV Investment Holdings LLC in the principal amount of $20.0 million (the “2024 Convertible Note”). On October 11, 2024, in conjunction with the Series C-1 Preferred Units financing and in accordance with the 2024 Convertible Note’s stated terms, the outstanding principal and interest of the 2024 Convertible Note of $20.1 million was converted into 3,097,477 Series C-1 Preferred Units.
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2024 Bridge Loan: On September 26, 2024, we entered into a bridge loan with Escape2, LLC, an entity affiliated with an owner and member of our Board of Directors (the “2024 Bridge Loan”), in the amount of $3.8 million. Concurrently with the issuance of this debt, the Company issued 124,430 Class B Common Units to Ghaffarian Enterprises. On October 11, 2024, in accordance with its stated terms, the 2024 Bridge Loan was automatically redeemed, and we paid the outstanding principal and interest associated with the 2024 Bridge Loan of $3.8 million.
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Series C-2 Convertible Notes: During 2022 and 2023, we issued convertible notes payable in an aggregate principal amount of $28.0 million and $85.0 million (“C-2 Notes”), respectively, of which $70.0 million of the C-2 Notes were issued to related parties. The C-2 Notes were scheduled to mature on September 30, 2025 and accrue 10.0% of payable-in-kind interest annually. On October 11, 2024, a
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portion of the C-2 Notes with an aggregate principal balance of $98.0 million converted into 16,960,021 Series C Preferred Units. On September 30, 2025, the remaining $18.4 million of outstanding principal and unpaid accrued interest on the C-2 Notes were converted into 2,870,172 Series C Preferred Units.
Please refer to Note 7 — Debt of our audited consolidated financial statements and unaudited condensed consolidated financial statements included elsewhere in this prospectus for additional information.
Off-Balance Sheet Arrangements
We have no off-balance sheet arrangements.
Cash Flows for the Nine Months Ended September 30, 2025 and 2024
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Nine Months Ended
September 30, |
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($ in thousands)
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2025
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2024
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Net cash used in operating activities
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| | | $ | (92,678) | | | | | $ | (47,961) | | |
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Net cash used in investing activities
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| | | | (41,766) | | | | | | (257) | | |
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Net cash provided by financing activities
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| | | | 50,230 | | | | | | 62,186 | | |
Operating Activities
During the nine months ended September 30, 2025, our operating activities used $92.7 million of net cash as compared to $48.0 million during the nine months ended September 30, 2024. The increase in cash used in operating activities is primarily driven by an increase in activity on the ARDP contract, an increase in corporate headcount, and an increase in technology and corporate contractors during fiscal year 2025.
Investing Activities
During the nine months ended September 30, 2025, our investing activities used $41.8 million of net cash as compared to $0.3 million during the nine months ended September 30, 2024. The increase in net cash used in investing activities was primarily attributable to a $79.3 million increase in capital expenditures related to the construction of new facilities. This increase was partially offset by a $37.6 million in reimbursements received during the period for capital expenditures qualifying under government grant programs.
Financing Activities
During the nine months ended September 30, 2025, financing activities provided $50.2 million of net cash as compared to $62.2 million during the nine months ended September 30, 2024. The net cash provided by financing activities during the nine months ended September 30, 2024 was primarily due to proceeds received from debt instruments of $139.1 million, partially offset by $75.1 million of cash repaid on lines of credit. The cash received from financing activities during the nine months ended September 30, 2025 primarily relates to the January 2025 issuance of Series C-1 Preferred Units of $53.4 million, offset by $2.7 million of cash paid for issuance costs.
Cash Flows for the Years Ended December 31, 2024 and 2023
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Fiscal Year Ended
December 31, |
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($ in thousands)
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2024
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2023
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Net cash used in operating activities
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| | | $ | (96,159) | | | | | $ | (159,580) | | |
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Net cash used in investing activities
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| | | | (1,865) | | | | | | (1,898) | | |
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Net cash provided by financing activities
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| | | | 598,340 | | | | | | 103,081 | | |
Operating Activities
In fiscal 2024, our operating activities used $96.2 million of net cash as compared to $159.6 million in fiscal 2023. The decrease in cash used in operating activities was primarily driven by a reduction in activity on
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the ARDP contract while the Company focused on raising capital. Additionally, in 2024 the Company paid approximately $20.3 million of costs incurred in 2023 related to the SPAC activities.
Investing Activities
In fiscal 2024 and 2023, our investing activities used $1.9 million of net cash.
Financing Activities
In fiscal 2024, financing activities provided $598.3 million of net cash as compared to $103.1 million in fiscal 2023. The increase in net cash provided by financing activities from fiscal 2023 to fiscal 2024 was primarily due to the receipt of proceeds from the issuance of Series C-1 Preferred Units of $626.5 million, offset by payments of issuance costs of $10.8 million, amounting to $615.7 million. There was also an increase in proceeds from debt instruments of $93.2 million, further increased by a decrease in payments of debt issuance costs of $1.6 million, amounting to $94.8 million, in fiscal 2024. The increase in net cash provided by financing activities was partially offset by an increase in repayments of debt instruments in fiscal 2024 amounting to $108.0 million, a decrease in proceeds from issuance of Series C Preferred Units in fiscal 2023 amounting to $79.3 million, and a decrease in proceeds from issuance of C-2 Notes in fiscal 2023 amounting to $28.0 million.
Contractual Obligations and Commitments
In addition to our contractual obligations and commitments described under “— Liquidity and Capital Resources,” we lease real estate for office space. These leases are classified as operating leases with various expiration dates through 2037. See Note 8 — Leases of our audited consolidated financial statements and unaudited condensed consolidated financial statements included elsewhere in this prospectus for more information regarding our lease commitments.
Critical Accounting Policies and Estimates
We believe that the following accounting policies involve a high degree of judgement and complexity.
Accordingly, these are the policies we believe are the most critical to aid in fully understanding and evaluating our consolidated financial condition and results of our operations. See Note 2 — Summary of Significant Accounting Policies and Recent Accounting Pronouncements to our audited consolidated financial statements and unaudited condensed consolidated financial statements appearing elsewhere in this prospectus for a description of our other significant accounting policies.
The preparation of our consolidated financial statements and unaudited condensed consolidated financial statements and related disclosures requires us to make estimates and judgements that affect the amounts reported in those financial statements and accompanying notes. Although we believe that the estimates we use are reasonable, due to the inherent uncertainty involved in making those estimates, actual results reported in future periods could differ from those estimates.
Revenue and Cost Recognition
The Company generated all of its services revenue from contracts with customers, a substantial portion of which was generated from contracts with the U.S. Government. A majority of the Company’s contracts with the U.S. Government are generally subject to the Federal Acquisition Regulation and are priced based on estimated costs of providing the contractual services.
The Company accounts for a contract when the parties have approved the contract and are committed to perform on it, the rights of each party and the payment terms are identified, the contract has commercial substance, and collection of substantially all of the consideration is probable.
The Company evaluates if its contracts are partially in the scope of ASC 606, Revenue from Contracts with Customers, and partially in the scope of other guidance. For contracts partially in the scope of other guidance, the Company separates and allocates the arrangement consideration to those components in accordance with ASC 606 unless the other guidance provides its own separation and allocation guidance.
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At contract inception, the Company determines whether the services to be provided are to be accounted for as a single performance obligation or as multiple performance obligations. This evaluation requires professional judgment, and it may impact the timing and pattern of revenue recognition.
The Company’s contracts may include variable consideration, such as adjustments to pricing based on performance or other contractual terms. Variable consideration is estimated at contract inception and updated throughout the contract term as additional information becomes available. The Company includes variable consideration in the transaction price only to the extent that it is probable that a significant reversal of cumulative revenue recognized will not occur when the uncertainty associated with the variable consideration is resolved.
The Company generally recognizes revenue over time throughout the performance period as the customer simultaneously receives and consumes the benefits provided on services-type revenue arrangements. The Company satisfies its performance obligation as services are rendered. An input method is used for cost based contracts, based on the cost of services which correspond directly with the value of the Company’s performance completed to date. For fixed-fee contracts, the Company applies an input method — specifically the cost-to-cost approach — where revenue is recognized in proportion to costs incurred, reflecting progress towards complete satisfaction of the performance obligation.
Contract modifications are reviewed to determine whether they should be accounted for as part of the original performance obligation or as a separate contract. When a contract modification changes the scope or price and the additional performance obligations are at their standalone selling price, the original contract is terminated and the Company accounts for the change prospectively when the new services to be transferred are distinct from those already provided. When the contract modification includes services that are not distinct from those already provided, the Company records a cumulative adjustment to revenue based on a remeasurement of progress towards the complete satisfaction of the not yet fully delivered performance obligation.
The Company utilizes other parties in the performance of some services. Using a control model, the Company evaluates whether it has promised to provide services to the customers as a principal or to arrange for services to be provided by another party as an agent. Based on the Company’s evaluation using a control model, the Company determined that in all of its performance obligations, it serves as a principal rather than an agent within its revenue arrangements. Revenue and the associated expenses are both reported on a gross basis within the consolidated statements of operations and comprehensive loss.
Financial Instruments and Fair Value Measurements
For our financial assets or liabilities that are carried at fair value and remeasured on a recurring basis, we utilize valuation techniques that maximize the use of observable inputs and minimize the use of unobservable inputs to the extent possible. We estimate fair value based on assumptions that active market participants would use in pricing an asset or liability in the principal or most advantageous market.
When considering market participant assumptions in fair value measurements, the following fair value hierarchy distinguishes between observable and unobservable inputs. Fair value measurements are categorized according to the criteria below based on the lowest level of input that is significant to the overall fair value measurement of the instrument:
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Level 1 inputs: Unadjusted quoted prices in active markets for identical assets or liabilities accessible to the reporting entity at the measurement date;
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Level 2 inputs: Other than quoted prices included in Level 1 inputs that are observable for the asset or liability, either directly or indirectly, for substantially the full term of the asset or liability; and
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Level 3 inputs: Unobservable inputs for the asset or liability used to measure fair value to the extent that observable inputs are not available, thereby allowing for situations in which there is little, if any, market activity for the asset or liability at the measurement date.
Recent Accounting Pronouncements
Please refer to Note 2 — Summary of Significant Accounting Policies and Recent Accounting Pronouncements of our audited consolidated financial statements and unaudited condensed consolidated financial statements included elsewhere in this prospectus for additional information.
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Quantitative and Qualitative Disclosures about Market Risk
We are exposed to market risks in the ordinary course of our business. Market risk represents the risk of loss that may impact our financial position due to adverse changes in financial market prices and rates. Our market risk exposure is primarily the result of fluctuations in foreign currency exchange rates and interest rates. Information related to quantitative and qualitative disclosure about this market risk is set forth below.
Foreign Currency Exchange Risk
Currency exchange rate fluctuations may impact our results of operations and cash flows. Foreign currency translation gains and losses arising primarily from changes in exchange rates on foreign currency transactions and balances are not hedged and are recorded in other expenses, net in the consolidated statements of operations and comprehensive loss. We do not trade in financial instruments for speculative purposes. Business is generally transacted in a single currency not requiring meaningful currency transaction costs. As such, a 10% or greater move in exchange rates versus the U.S. dollar would not have a material impact on our financial results and position.
Interest Rate Risk
The Company had two debt instruments outstanding during the nine months ended September 30, 2025 and year ended December 31, 2024 which are subject to a floating interest rate, the Bank of New York Credit Facility and Live Oak Credit Facility. Neither debt instrument had an outstanding balance at September 30, 2025 and December 31, 2024. As of September 30, 2025 and December 31, 2024, we did not have any interest rate swaps. As no amounts were drawn on September 30, 2025 and December 31, 2024, a 10% movement in the variable rate on our indebtedness would not have a material impact on our financial results and position.
We had cash and cash equivalents of $426.8 million and $514.6 million as of September 30, 2025 and December 31, 2024, respectively. Cash and cash equivalents consist of cash deposits, cash held in financial institutions and short-term investments purchased with an original maturity of three months or less. Our cash and cash equivalents are held for working capital purposes. Such interest-earning instruments carry a degree of interest rate risk. The primary objectives of our investment activities are the preservation of capital, the fulfillment of liquidity needs, and the fiduciary control of cash. We do not enter into investments for trading or speculative purposes. Due to the short-term nature of these instruments, a 10% change in interest rates during any of the periods presented would not have had a material impact on our consolidated financial statements as of September 30, 2025 and December 31, 2024.
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NUCLEAR INDUSTRY OVERVIEW
This section includes industry and market data, including our general expectations and market position, market opportunity and market size, as well as future growth rates relating to our market opportunity and the industry and markets in which we operate, that is based on industry publications and other published industry sources prepared by third parties. Although we believe the industry and market data to be reliable as of the date of this prospectus, this information could prove to be inaccurate. Moreover, projections, assumptions and estimates of the future performance of the industry in which we operate, including future growth rates and related estimates, forecasts and projections relating to the industry in which we operate and our market position, market opportunity and market size, are prospective in nature. Any such projections, assumptions and estimates are necessarily subject to a high degree of uncertainty and risk due to a variety of factors, including those described in the sections captioned “Risk Factors” and “Cautionary Note Regarding Forward-Looking Statements” elsewhere in this prospectus. These and other factors could cause any such projections, assumptions and estimates, to differ materially from those expressed in the projections, assumptions and estimates made by third parties and by us and you are cautioned not to give undue weight to such projections, assumptions and estimates. See “Market and Industry Data” for further information and important limitations and uncertainties regarding the industry and market data we present.
Evolution of Generation IV nuclear fission technologies
The existing nuclear fleet in the U.S. is largely considered “Generation II”, and consists of Pressurized Water Reactors (PWRs) and Boiling Water Reactors (BWRs), making up about 2/3rd and 1/3rd of the fleet, respectively. Both produce steam directly inside the reactor vessel to power the turbine, with condensed steam recycled back into the core. Newer “Generation III” systems, all Advanced Boiling Water Reactors and predecessor to Gen III+, were brought online in the 1990s, when few new nuclear reactors were built globally. No Gen III plants are in service in the U.S.
Small modular reactors have become more advanced as close following “Generation III+” reactor designs come online, including the AP1000 at Vogtle Units 3 and 4, offering significant improvements in safety with the introduction of passive safety features. Gen III+ includes both large conventional reactors and SMRs that adopt similar new safety features into a smaller, more compact design, generally considered to be around 10 MW to around 300 MW in size.
Advanced nuclear reactor technologies considered Gen IV are differentiated by their cooling methods and fuels that offer advantages in performance, safety and use cases (e.g., higher heat for industrials). The Xe-100 is considered a Generation IV reactor, but is based on decades of research that have brought these non BWR/LWR-based design concepts to commercialization. These technologies include:
High Temperature Gas-cooled Reactor: A Generation IV design using helium coolant and graphite moderator, operating at 700-950 °C. Fuel uses coated particle technology for high safety margins. Produces both electricity and industrial process heat. Modular HTGRs emphasize passive safety, low use and versatile energy applications. Currently, only China has commercially deployed HTGR technology. China’s HTR-PM project was formally launched in 2001, with basic design completion in 2008, and commercial operation in 2021 at Shidaowan. It is a 210 MWe demonstration plant consisting of two modular 250 MWt pebble-bed HTGR units.
Sodium-Cooled Fast Reactor: A fast-spectrum reactor cooled by liquid sodium, allowing efficient neutron economy and closed fuel cycles. Operates at near-atmospheric pressure with high thermal conductivity. Enables actinide recycling, reducing long-lived waste. Challenges include sodium’s reactivity with air/water. Demonstration reactors exist globally, with Generation IV designs targeting sustainability and safety.
Lead-Cooled Fast Reactor: Uses molten lead or lead-bismuth eutectic as coolant in a fast neutron spectrum. Offers excellent passive safety, high boiling point, and corrosion resistance. Capable of long refueling intervals and creating, or breeding, fuel. Challenges include structural material compatibility and coolant handling.
Molten Salt Reactor: Employs liquid fluoride or chloride salt as coolant, with fuel dissolved in salt or in solid form. Operates at low pressure and high temperatures (around 700 °C), enhancing efficiency and safety.
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Compatible with thorium fuel cycles and actinide recycling, which reduces the radioactivity and half-life of the nuclear waste. MSRs offer inherent safety features but face material and chemistry challenges.
Supercritical Water-Cooled Reactor: A high-efficiency design using water above its critical point (around 374 °C, 22 MPa) as coolant and moderator. Achieves thermal efficiencies greater than 45% with simpler, once-through steam cycle. Operates in thermal or fast neutron spectra. Challenges include material durability under extreme conditions.
Gas-cooled Fast Reactor: GFRs use helium as coolant and operate with a fast neutron spectrum. Core materials are advanced ceramic composites, tolerating outlet temperatures around 850°C. GFRs aim for high efficiency, closed fuel cycles, and hydrogen production. The design faces challenges in fuel development, decay heat removal, and structural material resilience.
See below for a comparison table across Generation IV reactors compiled by the U.K.’s Nuclear Innovation and Research Office (NIRO) as an objective view of the different advanced reactor concepts.
![[MISSING IMAGE: tb_evolutiongenera-4clr.jpg]](https://cdn.kscope.io/66e241b40ec9a8be53aefe262681fd00-tb_evolutiongenera-4clr.jpg)
Note: A higher performing system scores a higher number. For example, with economic cost a low-cost system would score ‘very high’ and a high-cost system would score ‘low.’
Fuel value chain overview
The supply chain for nuclear fuel is dependent on a select few countries that contribute uranium ore and enrichment capabilities. Uranium ore reserves are concentrated in deposits across the world with about two-thirds of the global production of uranium ore coming from mines in Australia, Kazakhstan and Canada. Once the uranium ore is mined and refined it needs to be enriched. Only nine countries have commercial enrichment capabilities: Russia, the U.K., Germany, Netherlands, the U.S., France, China, Japan and Brazil. The enrichment process is a critical step in the nuclear fuel cycle that enables nuclear energy generation and depends on the following critical steps: (i) Uranium ore is mined from both surface and underground mines, (ii) Uranium ore is milled into yellow cake, (iii) Yellow cake is chemically converted to uranium hexafluoride gas (“UF6”) to prepare it for enrichment, (iv) UF6 is enriched to increase the concentration of U-235 by using enrichment centrifuges that separate gaseous uranium isotopes. There are three categories of enriched uranium, LEU with enrichment of less than 5%, HALEU with enrichment between 5% – less than 20% and High Enriched Uranium (“HEU”) with enrichment of greater than or equal to 20%. X-energy’s Xe-100 reactor uses 15.5% enriched uranium for its fuel. The final steps in the fuel supply chain involve the process of
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deconversion, fabrication of fuel pellets, kernels and assembly into final fuel forms (e.g. TRISO pebbles, compacts) and final fuel configurations which are then used to produce nuclear energy.
Conventional nuclear reactors based on Generation II and III technology such as PWRs and BWRs use LEU for fuel to generate electricity. There is currently a greater supply of LEU-based fuel due to market demand, government support, and a simpler enrichment process to achieve a lower (less than 5%), level of enrichment, and because of this, there is an established global supply chain for this type of fuel. Generation IV technologies including Advanced Small Modular Reactors use HALEU as input for fuel and certain Generation IV reactors, including the Xe-100, rely on a specific HALEU-based fuel called TRi-structural ISOtropic fuel (TRISO) to generate electricity.
![[MISSING IMAGE: fc_miningconversation-4clr.jpg]](https://cdn.kscope.io/66e241b40ec9a8be53aefe262681fd00-fc_miningconversation-4clr.jpg)
Differentiation for HTGRs among SMR and Gen IV technologies
Benefits of TRISO fuel
TRISO fuel was developed in the 1960s in the U.K. and Germany for High Temperature Gas-cooled Reactors and was later adopted in the U.S. for research during the 1970s-1980s. The DOE revived the fuel in the 2000s under the Advanced Gas Reactor Fuel Development Program to support research efforts for the next generation reactors. Current TRISO fuel production in the U.S. is limited to R&D and low-volume production for DOE reactor demonstration programs. This is being expanded through new government efforts to secure a U.S.-based uranium enrichment supply chain that will enable additional fuel form production. First, the U.S. government plans to bridge the supply of HALEU until private enrichment plants can operate at scale. Second, private actors such as Centrus and Urenco are being supported by DOE cost-sharing contracts to accelerate commercial operation. DOE’s stated goal for such commercial efforts is for plants to come online as early as 2027.
TRISO fuel consists of uranium fuel kernels individually encapsulated in multiple layers of pyrolytic carbon and silicon carbide, forming miniature containment systems that trap fission products. These particles are then embedded in a graphite matrix to make fuel pebbles and compacts that possess exceptional safety margins and compacts, enabling operations at very high temperatures.
Additional benefits of TRISO fuel include:
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high fuel efficiency that can achieve a 19% maximum burnup rate which is around 4x higher than current LEU yields and significantly higher than other HALEU-based fuels including uranium nitride which have burnup rates of up to 8%, allowing reactors to run longer between refueling and reduce overall downtime;
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longer operational life of reactors due to the fuel’s durable structure and resistance to neutron irradiation, corrosion and oxidation;
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robust structure as TRISO pebbles are manufactured to withstand high temperatures and cannot melt down as well as prevent the release of radioactive nuclear materials due to its advanced coating structure;
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versatile fuel form as it can be used for various reactor technologies including High Temperature Gas-cooled, Molten Salt and Micro reactors;
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can be made from both LEU and HALEU; and
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complex and layered fuel design that makes it more difficult for enriched uranium proliferation.
Benefits of Helium as a Coolant
While other gases have been investigated, helium has emerged as the coolant of choice for HTGRs through decades of research on the properties of the gas that make it uniquely suited for the high temperature safety requirements. As a noble gas, helium’s chemical inertness, prevents corrosion of reactor components and ensures long-term structural integrity. It aids in efficient heat transfer and doesn’t become radioactive under neutron exposure. As it remains in gaseous form throughout all operating temperatures of the reactor, the use of helium eliminates concerns about phase changes and thermal stress on the reactor components. Helium is also transparent and non-toxic, enabling easier visual inspection and safety use cases for the reactor serving lifetime. With a helium outlet temperature of 750°C in the Xe-100 HTGR design, the use of helium enables significantly higher steam production temperatures than conventional reactors.
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BUSINESS
Unless the context otherwise requires, all references in this section to the “Company,” “X-energy,” “we,” “us” or “our” refer to the business of X-Energy, Inc. collectively.
OVERVIEW
Our company
X-energy is a leading designer of advanced nuclear reactor technology (commonly referred to as small modular reactors, “SMRs”) and manufacturer of advanced nuclear fuels. We believe these scalable, power generation technologies help satisfy historically unprecedented electricity demand growth, driven by the development of AI and associated data center infrastructure. Total demand for new electricity generation is expected to increase globally by 7,626 TWh from 2023 to 2030 and the challenges associated with meeting this demand have led policymakers and industry leaders to recognize nuclear energy, particularly advanced nuclear, as a key component to address this need.
Founded in 2009 by Dr. Kamal “Kam” Ghaffarian to bring clean, safe, secure and affordable technology to market, X-energy is seeking to redefine the energy industry through its flagship product, the Xe-100, an advanced small modular HTGR, in development for nearly a decade. The Xe-100 reactor is designed to generate 80 megawatts of electric power or 200 megawatts of thermal output (heat), or a combination thereof. This reactor technology builds on more than 50 years of research and development by the global nuclear industry and the operating experience of previous HTGRs including those at Peach Bottom in the U.S., and Dragon in the U.K. in the 1960s-1970s, and more recently with China’s ongoing deployments of HTGRs in the 21st century.
The Xe-100 has several technological attributes that we believe make it advantaged compared to other sources of baseload generation. These include advanced safety features, virtually no direct GHG emissions during generation, high thermal output, load-following capabilities and modularity, all of which allow X-energy to more specifically meet a customer’s power and/or industrial heat needs. X-energy’s simple Xe-100 design directly translates into simplicity of project delivery through reduced supply chain complexity and labor intensity during construction, which we believe will lead to lower cost and faster deployment timelines when compared with conventional nuclear energy sources. X-energy has optimized the deployment of its Xe-100 into a four-reactor format that outputs 320 MWe (or 800 MWt). By deploying four independent reactor modules instead of a single unit, this optimized four-reactor configuration inherently delivers the high levels of reliability and redundancy required for both AI and industrial heat applications.
X-energy’s reactors use a TRISO coated particle fuel in the form of a spherical ‘pebble’, called TRISO-X fuel. This pebble fuel consists of HALEU fuel kernels individually encapsulated in layers of silicon carbide and pyrolytic carbon, forming miniature containment systems that trap fission products. These particles are then embedded in a graphite matrix to make fuel pebbles that possess exceptional safety margins and compacts, enabling operations at very high temperatures. The HALEU fuel used in our TRISO-X pebble fuel is enriched to 15.5%, a higher energy density form than the less than 5% LEU fuel used in conventional nuclear reactors. TRISO-X fuel will be produced at our fuel fabrication facility in Oak Ridge, Tennessee. The first facility, known as TX-1, began construction in October 2024 and is expected to be completed by the first half of 2028. Upon completion, it is expected to be North America’s first purpose-built commercial advanced nuclear fuel fabrication facility. The TX-1 facility will have sufficient production capacity to support the fuel needs of the first 11 Xe-100 reactors at steady state operations.
In addition to its technology leadership, X-energy has three high-quality customers in Dow, Amazon, and Centrica, who we expect will underpin the deployment of the initial fleets of Xe-100 reactors. Taken together, assuming each customer exercises its contingent rights in full, these three customers provide us with a more than 11 gigawatts electric (“GWe”), 144 reactor pipeline across the U.S. and the U.K. with advanced development efforts already underway on the first Dow project at its Seadrift Operations site in Texas and the first Amazon project in connection with Energy Northwest.
X-energy maintains a strong relationship with the DOE and in December 2020 was awarded an initial $1.2 billion project as part of its selection as one of two awardees in the ARDP, the most substantial federal
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commitment to deploying advanced nuclear technology. The cooperative agreement for the program, signed in March 2021 (the “ADRP Agreement”), provides 50/50 cost share, allowing X-energy to finish the remaining design, licensing, commercialization and construction of its first-of-a-kind commercial advanced nuclear plant and commercial TRISO-X fuel fabrication facility, while benefiting from decades of nuclear experience and knowledge within the DOE.
Our Market Opportunity
Load growth is accelerating globally with the IEA estimating electricity consumption to grow by more than 25% from approximately 30,000 TWh in 2023 to approximately 37,000 TWh by 2030. In the U.S., power demand is being driven by the increasing data center buildout from cloud computing providers, industrial growth and reshoring of manufacturing, and broader electrification (e.g., electric vehicle installed base). Other sources (BNEF New Energy Outlook 2025) also indicate that power demand is being driven by growing load growth demand from AI and industrial use. Policymakers and industry leaders recognize that nuclear, particularly advanced nuclear, will be a key contributor to meeting this load growth and securing America’s energy independence, with the stated goal of the current federal administration to expand U.S. nuclear capacity to 400 GWe by 2050 (from approximately 97 GWe at present).
We believe the market for SMRs is vast and that X-energy is well positioned to capture this opportunity. According to a 2024 report from PA Consulting, the U.S., the U.K. and Canada, X-energy’s planned core markets, comprise approximately one-third of potentially serviceable global electricity usage. Across these three geographies, there is an estimated TAM of cumulative capacity additions of 743 GWe and 1,146 GWe by 2040 and 2050, respectively. Of this TAM, PA Consulting estimates 72 GWe in 2040 and 158 GWe in 2050 will be best served by SMRs based on needs, siting efficiencies, and demand for co-generation. These capacity additions, across a representative set of SMR use cases including powering data centers, utility power generation, industrial applications and BTM generation, implies a potential need for approximately around 1,975 Xe-100 reactors (the equivalent of 494 four-reactor deployments), or an estimated $2.3 trillion market opportunity for X-energy in 2050.
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We believe the following secular movements will continue to support the use cases and power needs for scalable, firm, clean baseload power that SMRs, particularly the Xe-100, can deliver.
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Demand for AI is Prompting Investment in Nuclear Power Generation. Cloud computing providers and AI companies are deploying capital across data center infrastructure to keep up with the growing
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computing demand required by AI. As part of this expansion, electricity demand in the U.S. from data centers is expected to grow from approximately 108 TWh in 2020 to approximately 426 TWh by 2030. Since data center facilities must be continuously powered, nuclear generation can provide a key solution for reliable supply. SMRs are particularly well suited to meet the average 300 MW to 1,000 MW power capacity that data centers require. SMRs have a smaller physical footprint to meet siting requirements, and have modular scalability which provides the flexibility to meet facility-specific capacity needs.
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High Carbon-Intensity Industrials Require Replacement for Industrial Heat and Steam Production. Industrial companies have historically relied on fossil fuel fired boilers to generate electricity and steam for their industrial processes. The current installed base of industrial boilers operates below capacity and is frequently offline for maintenance. The current fleet is facing a near-term replacement cycle due to age. For industrial processes requiring consistent steam availability, X-energy’s HTGR solution can reliably provide industrial steam in addition to onsite power. With an expected capacity factor of 95%, X-energy’s SMR presents a compelling replacement opportunity for aging infrastructure to both decarbonize and achieve greater reliability.
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Current Alternatives Are Not Well-Suited to Deliver Reliable, Uninterrupted, Clean, and Co-Located Power.
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Renewables with or without energy storage — Solar and wind generation have relatively low-capacity factors (i.e., the actual energy output in a given period of time relative to its theoretical maximum output) of 23% and 33% (EIA) respectively, since they only produce power when the sun is shining or the wind is blowing. Addressing this inherent intermittency issue would require the integration of large-scale battery energy storage systems or supplementary dispatchable generators for the production capacity of these renewables to even be comparable with the anticipated 95% capacity factor of our reactor. Large-scale deployment of battery storage is complicated by global supply chain availability and incremental cost.
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Conventional fossil fuel generation with or without carbon capture — Standalone fossil fuel fired generation can deliver capacity factors similar to those of nuclear power but often require backup generation when maintenance takes key assets offline. Conversely, the Xe-100 can deliver critical redundancy due to its modular nature which results in a reliability advantage without requiring grid redundancy. Further, many consumers have climate targets, giving SMRs (with virtually no direct GHG emissions from energy generation) a distinct advantage over carbon-intensive alternatives such as coal, oil, and natural gas generation, which would require pairing them with expensive carbon capture solutions to try to meet climate targets.
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Traditional Nuclear Power — Large-scale nuclear, while typically operating around-the-clock (other than planned outage maintenance and refueling cycles, as compared to the Xe-100’s online refueling), requires a large footprint and has consistently suffered from historical project delays and cost overruns. By contrast, advanced nuclear requires a much smaller operating footprint, on average about 1/4th to 1/10th that of a traditional nuclear plant. Additionally, HTGR sites in the U.S. will require a significantly smaller safety zone radius (400 meters versus 16 kilometers) because of built-in passive safety features. These safety characteristics enable lower costs and more compact designs due to a reduction in the quantity of concrete and steel safety infrastructure. The smaller overall footprint of SMRs allows co-location with new power demand hubs, and the modular nature of the Xe-100 enables scalable power output through additional on-site reactors to match specific needs.
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Ongoing Support from the U.S. Government Beyond the ARDP. Support for nuclear power has been increasing over the past decade with billions of additional dollars being allocated to nuclear energy through recent energy-related legislation. For instance, the OBBBA, signed in July 2025, maintained tax credits that were first introduced as part of the Energy Policy Act of 2005 and later expanded under the Inflation Reduction Act for nuclear projects. Additionally, the U.S. President issued four Executive Orders in May 2025, including support for the acceleration of regulatory review for advanced nuclear reactors and promotion of investment in a domestic nuclear supply chain. We believe these broader initiatives, building from U.S. nuclear policy precedent, will provide long-term support for advanced nuclear reactors like the Xe-100.
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Investing in a Domestic HALEU Supply. Establishing a domestic HALEU supply for the growing advanced nuclear reactor market in the U.S. is a top priority for the U.S. Government. Through the Energy Act of 2020 Congress established the HALEU Availability Program and has authorized the DOE to make HALEU available for civilian use (e.g., initial ARDP core loads) until commercial supply chains are in place. The program provides surety of offtake through a revolving fund that will provide the market surety needed to jump-start enrichment services and HALEU production, stimulate private investment and build a commercial-scale U.S. domestic fuel supply chain encompassing mining, conversion, enrichment, fuel fabrication and transportation. Congress has appropriated a total of $3.4 billion for these activities.
Key public-private partnerships established under the HALEU Availability Program include enrichment services with companies Centrus Energy, Urenco, Orano and General Matter. DOE will place orders through Indefinite Delivery / Indefinite Quantity contracts under a 10-year framework to provide enrichment services for the DOE. Centrus is already producing approximately 1 MTU of HALEU per year through its pilot cascade at Piketon, Ohio, and has the ability to add an additional cascade every six months, enabling scalable increases in HALEU production as demand and funding allow. By the first quarter of 2029, Centrus aims to produce up to 6 MTU of HALEU annually. The DOE has recently announced the initial allocation of HALEU to select SMR developers, with X-energy receiving the first tranche equivalent of 4 MTU. The program is expected to provide X-energy a total supply of around 7.6 MTU, enough for X-energy’s first Xe-100 plant with Dow.
Longer term, Urenco is working with the NRC to amend its license for HALEU enrichment, with expansion and production targeted for the early 2030s. Orano and General Matter are developing new enrichment facilities in Tennessee and Kentucky, with operations expected to begin as early as 2031 and 2034, respectively, which will further strengthen U.S. HALEU availability.
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Advanced Reactors Can Provide Supplemental Power to the Grid. Utilities see value-add opportunities to use SMRs like the Xe-100 for power generation to meet the growing electricity demand from their customers. As an example, the Tennessee Valley Authority and Canadian Ontario Power Generation have both filed construction permit applications with the relevant local regulators in their jurisdictions, with Ontario Power Generation receiving their nuclear power reactor construction license from the Canadian Nuclear Safety Commission in April 2025. Furthermore, Dominion Energy is discussing various scenarios for development of SMRs, including a plan to develop six SMRs starting in 2034. Additionally, Constellation Energy is in discussions with customers interested in developing SMRs at the company’s existing sites, increasing deployment speed and efficiency by avoiding new grid connections, security infrastructure, and other typical requirements for nuclear deployments.
SMRs like the Xe-100 are attractive to utilities for several reasons including:
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Targeted Incremental Load Growth. Load growth in many areas of the U.S. does not support the need for very large, centralized capacity additions that traditional nuclear LWRs provide, but rather, requires more incremental, distributed capacity that SMRs are able to provide. SMRs, because of their smaller, configurable capacities, allow for better matching of incremental load needs to more rapidly supplement existing facilities and benefit from existing site infrastructure.
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Safety Case and Relatively Smaller Operational Footprint. Due to the smaller operational footprint relative to alternatives, SMRs can be sited on existing, soon to be retired, or retired power plant locations. In doing so, utilities can benefit from existing approved siting and permitting, serving as a compelling option to deliver incremental, continuous baseload power more quickly and cheaply than greenfield sites.
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Financing Accessibility and Reduced Project Risk. SMRs, given their size, carry a lower capital investment burden than do traditional LWRs, making SMRs more accessible to customers including utilities. The costs to deploy traditional LWRs can reach $20.0 billion or more, representing a significant undertaking and financial pressure, even for larger utilities. SMRs, on the other hand, can be financed and built in phases, thereby offering smaller capital outlays that can be spread over several years while delivering power to the grid sooner than LWRs. This phased, repeated deployment
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also represents lower risk due to simpler, smaller construction projects with less capital at risk as compared to LWR projects, which have traditionally suffered from significant cost and schedule overruns.
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Proximity to Load Centers and Transmission Efficiency. SMRs’ small land requirements and superior safety case enable siting near existing load centers. By locating generation closer to demand, utilities can reduce or avoid the need for long, new transmission laterals that are often required for remote wind or solar resources, lowering interconnection costs, shortening schedules, and mitigating right-of-way, permitting, and community opposition risks. Closer siting also curtails line losses and congestion, improving delivered-cost economics and grid reliability while easing pressure on constrained transmission corridors. Repowering existing sites with SMRs may allow utilities to leverage established infrastructure, substation capacity, and prior environmental reviews, further accelerating deployment timelines and reducing execution risk.
Competitive Strengths
As pioneers of next generation nuclear reactor and fuel technologies, we believe that our collective expertise can allow us to capitalize on our competitive strengths. We believe we will establish a leadership position in the evolving market, including by leveraging the strengths of our early customer relationships to give us a differentiated path to success.
Existing Customer Base Provides Initial Momentum and Support. Both Dow and Amazon have supported our initial projects, and we expect will serve as offtake customers in the future. These initial projects also enable X-energy’s goal of scaling its design to two different offtake customer applications: Industrial Heat Applications and Data Center Projects. Dow and Amazon also provide project development insight through their own operations portfolios. X-energy expects to learn from and engage with these and other customers as it builds the pipeline. This repeatable project schedule, which is also anticipated for the recently announced Centrica partnership, is expected to enable X-energy to scale from First-of-a-Kind to an Nth-of-a-Kind model that we believe will reduce our project cost and significantly derisk future projects.
Differentiated Design that Provides Attractive Solution for Customers. The characteristics of the Xe-100 provide several advantages over many other energy production alternatives. First, traditional renewables like wind and solar cannot provide reliable baseload power without being paired with longer-term storage technologies. They are also dependent on exogenous factors, which make them incapable of quickly ramping up to address increases in demand. Second, the Xe-100 has a versatile design that can be applied to several end markets, including industrial heat and conventional power generation. In addition, other emerging SMR technologies, many of which are based on conventional LWR technology, may not be designed to efficiently load-follow or operate at temperatures high enough to provide industrial heat, and are further constrained by the availability of large amounts of water, a constraint that the Xe-100 does not have.
Improved Proven Technology. Unlike some other advanced reactor technologies, X-energy is leveraging HTGR technology that has been previously deployed across the globe, including in the U.S. at Peach Bottom and in the U.K. at Dorset (Dragon), and building on more than 50 years of research and development by the global nuclear industry. Both of these reactors served as proof-of-concept for the HTGR technology in the U.S. and, along with other HTGRs in Europe and Asia, provide valuable experience and data that X-energy has used to improve its design, leading to a more efficient, commercially deployable technology.
Intrinsically Safer Based on Physics without Needing Active Safety Systems. Our simplified Xe-100 reactor design is not dependent upon active safety systems, which are susceptible to failure and therefore necessitate the redundancy found in a typical LWR reactor design. Our design relies on physics and intrinsic safety features, such that in the event of a total loss of power to a Xe-100 reactor, the reactor does not require any operator or computer actions, grid connections, emergency backup power or additional water to cool the reactor. The reactor has a strong negative temperature coefficient, which means that increased temperature (such as from the loss of coolant circulation) slows the fission reaction, causing the reactor to shut down. Finally, due to the relatively low power density of the core, the remaining heat load is naturally dissipated through passive cooling.
Superior Fuel Based on Decades of Research & Development. We expect our TRISO-X fuel to demonstrate technical quality and a streamlined fuel qualification pathway, providing us a competitive edge in
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the commercial fabrication of TRISO fuel forms. The TRISO-X fuel used in the Xe-100 is a containment vessel itself and designed not to melt, enabling the technological and safety advantages of the HTGR. Due to decades of research, development and testing, including the DOE’s Advanced Gas Reactor (AGR) Fuel Development and Qualification Program, the TRISO-X particle fuel is relatively well understood. This historical data has established the parameters for TRISO-X fuel testing and qualification. Our TRISO-X pebble fuel qualification methodology is approved by the NRC, and we have a streamlined path towards final fuel qualification by the time of our first Xe-100 deployment.
Attractive Intellectual Property-Driven Business Model. X-energy serves as both a reactor technology provider and a fuel fabrication provider, offering customers an integrated solution. In our reactor business line, we expect to receive technology fees for licensing use of our proprietary Xe-100 technology, while also receiving fees for coordinating assembly and construction support with customers and anticipated blue-chip third-party vendors. We also intend to leverage our knowledge and expertise in regulatory licensing, construction, procurement, operations, maintenance and other processes to provide customers with a full suite of services from the development of a project, and ultimately for the operating life of the reactors. We do not construct the power plants and do not plan to own or operate the power plants once constructed and, as a result, do not incur capital expenditures relating to constructing, maintaining, owning or operating the facilities. However, we intend to remain involved with the EPC process throughout the project by providing strategic consulting related to the integration of the reactor technology. We believe this intellectual property-driven business model will position us to generate attractive free cash flow.
Leading TRISO Fuel Provider. From our TRISO-X fuel manufacturing facilities in Oak Ridge, Tennessee, X-energy plans to provide customers with initial reactor fuel loads of as well as ongoing delivery of TRISO-X fuel required to refuel plants over the lifetime of a plant. This provision of fuel to our customers would generate a strong, recurring, revenue stream. X-energy’s fuel can also be fabricated for other advanced reactor technologies, making it a key enabler of the broader advancement of the SMR space. X-energy was selected to receive one of the first allocations of HALEU from the DOE. This HALEU is required to begin initial fuel production but X-energy does not, and does not intend to, bear any significant inventory risk associated with uranium or fuel feedstock. We intend to provide only fabrication supply services for customers and assume limited risks associated with holding the title to uranium or enriched uranium fuel feedstock.
Visionary Management Team and Highly Expert Employee Base. We have an experienced and passionate team of leaders and innovators who have been directly involved in the development of advanced nuclear technology and who have led large-scale nuclear projects and operations. As of January 1, 2026, we have a highly educated workforce of 889 employees, of whom 312 have master’s degrees and 107 have Ph.Ds. Our executive leadership team has experience in nuclear design, nuclear project delivery, nuclear fuel fabrication, operations, government relations and public companies in organizations such as OPG, GEH, the DOE, the Nuclear Regulatory Commission, Constellation Energy, Hunt Consolidated, BWXT, Westinghouse, Hartree Partners, and Emirates Nuclear Energy Corporation. The management team is led by our CEO, J. Clay Sell, who is one of the foremost leaders in the U.S. energy market. As the former Deputy Secretary of the DOE, he brings the perspective of the U.S. energy industry to X-energy. Further, his experience in renewables development after his time as Deputy Secretary has given him key experience in major project development and valuable insight into the limitations of intermittent renewable technologies, and in turn the value of nuclear generation.
Strength of Government Relationships. The ARDP significantly derisks the delivery of X-energy’s First-of-a-Kind reactor deployments through the Dow Project. Because of the 50/50 cost share program, X-energy has had significant ongoing engagement with the DOE and benefits from the DOE’s collective knowledge and support. Further, X-energy has developed high credibility with the Nuclear Regulatory Commission through our ongoing engagement for both our FOAK Fuel Fabrication facility and Dow projects, evidenced by the docketing of the first Construction Permit Application for an 18-month review schedule, one of the shortest CPA timelines ever given.
Our Business Model
We have an intellectual property-driven business model based on our reactor and fuel. We expect to derive revenues from technology licensing, services and fuel operations that span the development and operation of the reactors.
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Reactors: The revenue stream from reactors includes technology fees for the use of our intellectual property of the Xe-100 technology. We will not own and operate the facilities themselves, which we believe significantly reduces the amount of capital needed to operate our business.
We anticipate offering site-specific engineering and site characterization, project planning, assembly coordination, construction support, regulatory support, procurement support and long-term services to customers. Utilizing our knowledge and expertise in licensing, construction, procurement and other processes, we plan to provide customers with a full suite of value-added services during development of the nuclear power facilities. At the same time, we expect to generate long-term recurring revenue from services such as the ongoing maintenance and operator training through the anticipated 60-year life of a facility.
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Fuel: We intend to provide manufacturing services to customers, including producing an initial fuel load of both TRISO-X fuel and an LEU-based TRISO fuel at commissioning of a plant. We expect to generate additional long-term recurring revenue from our own proprietary TRISO-X fuel that is required to refuel plants during the anticipated 60-year life of each facility. We expect to bear limited inventory risks related to uranium or enriched uranium fuel feedstock. We intend to provide only fabrication supply services for customers and assume limited risks associated with holding the uranium or enriched uranium fuel feedstock. Additionally, we will not have any responsibility for spent fuel management beyond the design of such facilities to adequately handle spent fuel during the life of the plant. During operations, spent fuel remains the responsibility of the plant operator. Thereafter, permanent spent fuel management remains the responsibility of the DOE.
Lifecyle unit economics
We expect each of the four reactor Xe-100 projects (each such optimized four-reactor configuration referred to as a “plant”) to generate between approximately $2.7 and $4.7 billion in aggregate revenue across both our reactor business line and our fuel business lines, beginning with the pre-development phase of the plant and continuing through the plant’s anticipated operational design life of 60 years after the COD of such plant.
Reactor. Revenues from our reactor business line are expected to be comprised of both our technology fee and fees from our services offerings. We expect to earn these fees beginning with the pre-COD development phase of the plant and continuing throughout the operational life of such plant. We expect approximately 15 – 35% of revenue generated in our reactor line of business to be realized prior to (and including) COD. Within that approximately 15-35% of pre-COD revenue, we expect to charge both a technology fee, which we expect to earn across various plant development milestones before COD, and services fees related to reactor development. The remaining approximately 65-85% of revenue from our reactor line of business is expected to be from the provision of long-term services offered post-COD. We expect to charge our services offerings to customers based on time and materials, and based on our anticipated pricing of our services fees, we expect to generate approximately 50% of gross margin on these services. Our technology fee is expected to be charged to customers for use of our intellectual property and has no associated cost.
Fuel. Revenues from our fuel business line are expected to be comprised of fees generated from selling an initial fuel load at COD and from selling additional fuel throughout the operational life of a plant. We intend to generate fuel revenue from fabrication fees that we can charge to customers throughout the plant’s expected operational life. We expect the initial fuel load at COD to be equivalent to approximately 5% of each plant’s lifetime fuel needs (approximately 3 years), which represents approximately 10% of the total revenue we expect to generate from the fuel business line for each plant. Following COD, we expect continuous online refueling to generate approximately 90% of our fuel revenue through the remainder of the plant’s anticipated operational design life of 60 years. Given our vertically integrated business model, we have flexibility in the fabrication fees we charge customers, and we anticipate that as our fuel manufacturing capabilities scale and efficiency and utilization increase, our unit operating costs for fuel fabrication will decrease.
The table below provides an illustration of the expected timing and nature of the cash flows that we anticipate being able to generate from a single plant, based on and subject to the assumptions set forth below.
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Dollar figures below are in millions unless otherwise noted. Dollar figures are rounded to the nearest $10.0 million, percentages are rounded to the nearest 5%:
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Total Plant Life*
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Customer Fees
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Cost to X-energy
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Target Margin
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| Reactor | | |
$1,070 – 1,380
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$510 – 540
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50% – 60%
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Fuel
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$1,650 – 3,310
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$1,160 – 1,320
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30% – 60%
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| Total | | |
$2,720 – 4,690
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$1,670 – 1,860
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40% – 60%
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Total Plant Life includes up to eight years prior to COD, COD, and 60 years following COD.
Key Assumptions Underlying Unit Economics
General
The table above illustrates management’s current expectations regarding the relative allocation of customer fees, our costs, and resulting margins across business lines for a single plant. The figures are illustrative and based on the assumptions summarized below; they are not forecasts, targets, or guidance. Our ability to achieve the illustrative customer fees, cost, revenue and margins are sensitive to a variety of factors further described below and under “Risk Factors” elsewhere in this prospectus. Actual outcomes will depend on variables including customer negotiations and fee structures, market conditions, supply-chain costs and dynamics, manufacturing efficiency and utilization, financing assumptions, and customer adoption of optional service packages, any of which could cause material differences from the figures presented above. The table above assumes the plant is fully supplied from both TX-1 and TX-2; future plants that require additional fuel facilities may differ in cash flow. This “Lifecycle unit economics” discussion should be read together with “Risk Factors,” “Management’s Discussion and Analysis of Financial Condition and Results of Operations of X-energy,” “Business,” and our consolidated financial statements.
Technology Fee Structure and Pricing Assumptions
We expect to charge a technology fee for customers’ use of our Xe-100 technology intellectual property. For purposes of this section, the assumed fee reflects benchmarking of IP licensing and industrial technology fees across various similar industries and sectors, together with the experience of our team and ongoing customer discussions. The final fee will be negotiated on a case by case basis, reflecting project timing, customer profile and scope, and is expected to be paid over multiple development milestones, with the full amount paid by COD. Fees may change over time as plants come online, the technology matures, and competitors emerge.
The customer fee range reflects variability in the technology fee component, with lower fees assumed for initial plants and higher fees for later plants after scaling and validation. Because the technology fee relates to use of our intellectual property, the associated cost to us in the table above is assumed to be zero. We have not yet entered into technology, intellectual property or related agreements, and we can provide no assurances that customers will accept our anticipated fee structure or pricing.
Services Business Fee Structure and Pricing Assumptions
We plan to provide a full suite of services across all phases of project development, including site selection, permitting, engineering, training, and procurement support, and following COD, ongoing maintenance and operator training through the design life of a plant. These activities are organized around industry-standard front-end loading (FEL 0 – FEL 4) phases. For this section, services pricing is assumed on a cost-plus basis, comprising direct labor and overhead with a targeted margin informed by revenue generated to date from the provision of initial strategic business and other services we’ve provided to customers and potential customers, as well as from industry benchmarking and our team’s collective experience. We expect limited pre-COD services revenue, as most services fees are expected to be generated post-COD. Additionally, we assume that post-COD reactor revenue is services-only revenue, as the technology fee is expected to be paid in full by COD. Lastly, for each plant, we assume that customers will continue to rely on us as a service provider throughout the operational life of such plant. We do not construct, own, or operate plants and therefore do not incur
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related capital expenditures. As a result, the costs reflected above do not reflect the total cost required to build reactors, which cost is primarily borne by our customers and may be substantial.
Reactor costs to us reflect only services costs and consist of estimated direct costs, including labor, overhead, and other costs, which are subject to change with market dynamics and competition. Customer fees include a services component based on the targeted margin applied to these costs. To date, we have entered into limited services agreements and there is no assurance that customers will accept our overall proposed and anticipated fee structure or pricing or continue to contract solely with us in future periods. The presence of third-party service providers could introduce price competition, thereby reducing revenue and increasing costs.
Fuel Model and Assumptions
We intend to provide the initial fuel load at COD and to generate recurring revenue from our proprietary TRISO-X fuel required for refueling over the anticipated 60-year plant life. Each plant requires an initial core load (covering roughly the first three years of operation), followed by steady replenishment. We assume that we are the initial sole supplier of our proprietary fuel and that customers purchase all fuel from us. The emergence of third-party TRISO suppliers could introduce price competition, reduce revenue, and increase costs.
Fuel customer fees and revenue are based on an assumed price per pebble estimated from our fuel costs, including labor, materials, and overhead. Pricing is intended to recover operating, variable, and fixed costs and to provide a target margin sufficient to support financing of future fuel facilities, assuming a minimum utilization level. We expect to provide fabrication services only and do not anticipate bearing inventory risk for uranium or feedstock. We will not be responsible for spent fuel management beyond designing facilities to handle spent fuel during plant operations. Accordingly, the illustrative figures do not reflect inventory or spent fuel management costs.
The range of fuel customer fees primarily reflects the estimated price-per-pebble range, which may be affected by efficiency improvements, cost reductions, and external supplier dynamics. The range of fuel costs to us reflects operating, fixed, and variable costs, including labor, overhead, and other inputs, all of which may change with market conditions and competition. We have not yet entered into fuel supply agreements, and there is no assurance that customers will accept the anticipated fee structure or pricing or continue to purchase fuel solely from us.
Operating Lifetime Assumptions
Our economics are based on an anticipated 60-year operating life of a reactor. All nuclear power plants in the country have been designed with substantial safety, operational, and component performance margins. While the Atomic Energy Act of 1954 limits initial licensing to 40 years, the current operating fleet was designed to operate beyond that limit. Similarly, the Xe-100 is designed with substantial margins to support operation beyond the initial 40-year licensing term. The NRC and industry recognized this margin and established the license renewal program to approve subsequent 20-year licensing periods. In license renewal, the NRC and industry focus efforts on reviewing the ability to manage the aging of nuclear power plants through performance programs. For the current operating fleet, since license renewal did not exist when they were initially licensed, the development of these aging management programs occurs for the first time at the time of license renewal.
For the Xe-100, since the design is intended to operate for 60 years, X-energy is designing the reactor with aging management in mind. With the establishment and implementation of these programs from initial commissioning, the Xe-100 will be poised to easily achieve license renewal approval from the NRC. It should also be noted that the process to receive NRC approval for license renewal is well understood and the NRC has never denied a license renewal application. For all of the reasons stated above, X-energy considers it a very low risk that the NRC would not approve license renewals for the Xe-100.
Growth Strategies
We intend to grow our business by leveraging the competitive advantages of our differentiated and reliable Xe-100 technology and our strong customer and government relationships to achieve scale. We believe we have several avenues to achieve our growth objectives:
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Continue to Develop our Next Generation Technology. We intend to continue developing our reactor and fuel technology with the goal of achieving commercial delivery of our first fleets of reactors by the early 2030s. We have substantially advanced detailed design for the Xe-100 and are working with our engineering and construction partners to complete that process. Furthermore, we will work with our initial Xe-100 customers to complete the site-specific environmental studies required for licensing and progress toward the submission of the construction permit application, including the preliminary safety analysis report. We have produced TRISO-X pebble fuel in kilogram batch quantities in our fuel fabrication pilot facility and have begun construction on North America’s first purpose-built commercial advanced nuclear fuel fabrication facility in Oak Ridge, Tennessee.
Execute on Attractive Business Development Pipeline. We believe the market for our Xe-100 and TRISO-X fuel technologies is wherever non-intermittent, reliable power is needed. We are initially focused on deploying our advanced SMRs to both industrial (including large-scale chemical manufacturing) and cloud-based service provider customers (e.g. data centers) who have needs for both electric power and efficient production of high-temperature steam with high reliability needs. We also plan to serve traditional utilities and IPPs seeking to replace carbon-intensive fossil-fueled power plants in their jurisdictions.
Leverage Repeated Project Execution Learnings to Scale From FOAK to NOAK. Traditional nuclear has been plagued by cost and schedule overruns. Vogtle units 3 & 4 cost more than $16 billion each and were seven years over schedule in part because they were the first and second AP1000 reactors deployed in the U.S. While the fourth unit was reportedly approximately 20% less expensive than the third as learnings were applied, achieving expected Nth-of-a-Kind scale with standard costs and schedule timelines is possible only through repeated project delivery over a large order book. The DOE and industry experts expect that Nth-of-a-Kind delivery can unlock potential savings of more than 30%. Starting with Dow and Amazon, X-energy is already working to deliver eight reactors across its first announced sites at Seadrift, Texas and Richland, Washington, respectively. With substantial potential for further targeted pipeline with Amazon and Centrica, we expect to be able to achieve reductions in costs and the acceleration of schedule timelines as we deliver more reactors in the future. We believe that NOAK will be achieved through repetitive project execution and financial de-risking, including early supply chain engagement, construction timeline compression, and regulatory streamlining. As we apply lessons learned from each deployment, we expect these steps will significantly reduce overall project execution costs and risks for subsequent Xe-100 projects.
Continue Geographic Expansion. Our initial core markets are the U.S., Canada and the U.K., which have sophisticated regulators that are capable of licensing our technology. Beyond these initial geographies, which together represent only one-third of the serviceable energy consumption, we anticipate expansion into new markets where we already have customer engagement, including countries in Eastern Europe, the Middle East and East Asia.
Drive Technology Advancements. Using our innovative technology platform, we believe that we are well-positioned to continue making technology advancements over time. These improvements include optimizing the Xe-100 for industrial heat applications and innovations in the design to support steam outlet temperatures greater than 800° C to support more efficient hydrogen production processes.
Develop New Products. We continue to explore the development of innovative new products based on our core technology and varied use cases for our proprietary Xe-100 reactor, TRISO-X fuel and other microreactor technologies TRISO-X is currently performing fuel fabrication work for others whose reactor technologies also use TRISO-based fuel, including space applications. Similarly, our Emerging Technologies team is involved in U.S. government-funded studies (such as those from the DOD) for innovative remote powering and lunar applications that may involve our microreactor and related technologies.
Our Technology
X-energy was founded by Kam Ghaffarian. The technology used today was matured through the Pebble Bed Modular Reactor program, a South African public-private partnership which advanced high temperature gas-cooled reactor technology. X-energy initially focused on the conceptual design of the Xe-100, discussed below, with an emphasis on top-level requirements designed to meet the broadest set of use cases. The company has continued to mature the Xe-100 design and has expanded into the production of TRISO fuel. Finally,
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X-energy has developed the design for the XENITH microreactor and we continue to invest in other research and development efforts.
Xe-100 — Our High-Performing Reactor
The Xe-100 is an HTGR which is designed to have advantages in economics, reliability and safety over conventional LWRs and other advanced SMR designs. The Xe-100 is a Generation IV advanced nuclear technology that has been designed to remedy weaknesses associated with traditional LWR designs. The Xe-100 can efficiently produce electricity or process heat. When configured for electricity generation, each reactor can power an 80 MW turbine generator. Deployment of these reactors is scalable and is optimized in a four-reactor configuration to form a 320 MWe power plant.
After years of development, the Xe-100 design has matured into what is known as the preliminary design phase, the second of three typical engineering design phases. Design finalization is occurring in tandem to development of our first customer projects to ensure the design best meets their needs. Once the standard reactor design reaches maturity, the development process will be shortened for subsequent customer projects.
The Xe-100 has made substantial licensing progress. After several years of pre-application engagement, we supported Dow’s subsidiary, Long Mott Energy, LLC in submitting a construction permit application to NRC for the proposed advanced nuclear project that will use our Xe-100 reactor design in Seadrift, Texas. The pre-application engagement was important in helping de-risk the project, because licensing challenges or delays can have significant impacts on a project’s timing or design, or in some cases its viability. Citing the completeness and quality of the application, and the effectiveness of pre-application engagements, the NRC published an 18-month review timeline for the Dow project and will concurrently proceed with its environmental assessment.
Note: Figure is intended to represent an illustrative rendering and is for illustrative purposes only.
The Xe-100 has the following characteristics:
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Cleaner and more reliable — Like all nuclear reactors, HTGRs produce virtually zero direct GHG emissions during energy generation, are “always” on (at 95%+ availability), and provide firm, dispatchable power that is cleaner than most available firm alternatives.
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Online refueling capabilities designed to enable the Xe-100 to meet a requirement of 95%+ plant availability, unlike conventional nuclear facilities, which require shutdown and refueling every 18 – 24 months.
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Four individual reactors feeding into a common source allows for enhanced reliability so that even under downtime for a single reactor, customer electricity and steam requirements can be continuously met.
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Nuclear power has no carbon emissions from the power production, offering a cleaner alternative for major cloud-based service providers and industrial customers with decarbonization targets.
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Reactor is designed for the 60+ year operational life, longer than traditional natural gas burner alternatives and providing long-term certainty for customers.
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High burn-up fuel cycle (165,000 megawatt-days per ton of uranium) means the Xe-100 utilizes its fuel around 4.0x more efficiently than conventional reactors.
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Designed with Intrinsic Safety Features — The Xe-100 HTGR is safer by design and because of the intrinsic physics of the reactor, requires fewer mechanical safety systems than traditional nuclear as well as fewer personnel for operations.
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The Xe-100 leverages passive safety features and the inherent physics of its High Temperature Gas-cooled Reactor (HTGR) core, which is designed to shut down safely without operator intervention or external power in the event of an emergency.
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The Xe-100 requires only about one-sixth the number of active mechanical safety systems typically found in traditional large-scale LWR nuclear plants, such as those used in the current U.S. commercial fleet.
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This reduction is achieved by eliminating the need for systems like emergency core cooling, large-scale backup power, and extensive active containment measures, which are standard in conventional nuclear designs.
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With only four operator-controlled variables (control rods, helium circulator, feedwater pump and turbine throttle valve), opportunities for operator error are drastically reduced, and automated operations allow for significantly lower operator workload.
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Because of the low source term, the Xe-100 plant design requires a significantly smaller emergency planning zone of 400 meters compared to 16-kilometer zone required for traditional LWR nuclear plants.
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This compact safety footprint enables the use of commercial-grade structures for most of the site, rather than the specialized nuclear safety-grade construction required for conventional reactors, and allows for greater flexibility in siting the plant closer to end users and industrial facilities.
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More Secure — The TRISO-X pebble fuel is a containment vessel in itself, supporting the secure nature of the Xe-100.
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The TRISO-X fuel pebble is a containment vessel in itself, made of layers of encased in graphite, pyrolytic carbon and silicon carbide, and designed not to melt due to its ability to withstand extreme temperatures.
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TRISO-X fuel retains 99.99% of all radionuclides during operation and severe accidents.
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Each Xe-100 will use approximately 220,000 of our TRISO-X fuel pebbles, with approximately 18,000 uranium oxycarbide TRISO-X fuel particles in each pebble, which helps to contain fission products and aids in long term nuclear waste storage.
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Pebbles remain in the reactor longer and burn off higher-risk byproducts compared to other advanced reactor concepts.
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At full power approximately 175 pebbles are cycled into the reactor daily. Each pebble travels through the fuel handling system core on average 6 times before disposal.
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After a pebble has cycled through the reactor, the spent reactor fuel is itself a containment vessel, with limited remaining fissile material, substantially limiting proliferation risks.
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Spent fuel can then be transferred directly into dry storage, reducing risk for spent fuel management. Long-term fuel storage is the responsibility of DOE.
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Scalable — The Xe-100 is expected to be commonly deployed in its optimized four-reactor configuration of 320 MWe, referred to as the “Xe-100 plant,” with the opportunity to scale on site to additional reactors as needed.
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We believe the 320 MWe power profile of the four-reactor deployment (and its highly scalable nature) is uniquely suited to meet data center demand.
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The Xe-100 is expected to have lower overall construction costs compared to traditional large-scale nuclear reactors, due to its modular design, use of factory-fabricated components, and simplified safety systems.
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These features are intended to reduce the complexity and duration of on-site construction, minimize labor requirements, and allow for more predictable project schedules.
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As a result, historically significant challenges for conventional nuclear projects such as the risk of cost overruns and delays is substantially reduced.
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This cost efficiency not only broadens the addressable market for advanced nuclear but also makes the Xe-100 an attractive option for customers seeking firm, clean power at a competitive price point.
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Streamlined — Due to its superior intrinsic safety attributes, the Xe-100 design needs fewer safety-related specialized materials and therefore utilizes substantially more off-the-shelf components than traditional nuclear reactors, allowing for scalability from commercial vendors.
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Our elegant and simple design maximizes the use of off-the-shelf and factory-built components that are expected to be shipped to site using existing road and rail networks.
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A simpler reactor concept also minimizes complexity of the nuclear island development and construction.
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Strategic supply chain partners enable more off-site constructability and integration of key components and drastically reduces on-site construction costs, personnel, and time.
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We expect approximately 1/10th the number of people needed to construct compared to traditional nuclear.
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Versatile — In addition to electricity, the Xe-100 plant can be configured to deliver high temperature steam at 565°C, providing a solution for difficult-to-decarbonize industrial heat applications such as oil sands operations, mining, chemical production and petroleum refining and other industrial processes.
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By using helium as a coolant, the Xe-100 is configured to withstand higher pressure that enables the reactor to deliver heat at higher temperatures (750°C helium outlet temperature and 565°C steam from the steam generator) than conventional light water reactors (around 300°C), which are impacted by a phase change (i.e., higher temperatures would require higher pressures in LWRs).
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The Xe-100 provides necessary reliability of industrial heat applications in its commonly expected multiple-reactor deployment configuration, opening the market for industrial replacements and expanding TAM to behind-the-meter applications.
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Load-following — The Xe-100 is designed to ramp down from full power to 40% power in 12 minutes and ramp back up to full power in the same short time span.
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This capability allows for faster ramp for load-following than existing Generation III+ SMR and conventional large-scale nuclear technologies, providing near-immediate responsiveness to energy needs.
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Allows the Xe-100 to be relevant in both restructured wholesale markets and regulated energy markets, as well as supporting intermittent wind and solar generation.
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TRISO-X Pebble Fuel — Our Proprietary TRISO Fuel
Our reactors use TRISO particle fuel, a technology first developed in conjunction with the U.K.’s Dragon reactor in the 1960s. The DOE describes TRISO particles as “the most robust nuclear fuel on Earth.” We manufacture our own TRISO fuel using proprietary methods, through our wholly owned subsidiary, TRISO-X, LLC, to ensure supply and quality control. Further, many of the advanced nuclear reactor designs in development are expected to be powered by TRISO fuel or other coated-particle fuels. As part of our business model, we intend to not only sell TRISO-X fuel to our customers but to also fabricate and sell TRISO-X fuel and other encapsulated fuels to other advanced nuclear reactor customers, including governmental and private entities.
To be able to use this fuel in operating reactors, the fuel must first be qualified by the NRC. The TRISO-X pebble fuel qualification methodology has already been approved by the NRC. Following this methodology, X-energy is now undergoing irradiation testing on the TRISO-X pebbles at Idaho National Lab. This process began in 2025 and the campaign has an expected end date in the fourth quarter of 2026. Data from this campaign is then used in the subsequent testing, evaluation, and ultimate qualification of our fuel form by the NRC.
At commissioning, the initial fuel load for the reactor core of the Xe-100 will include both ‘blank’ graphite pebbles, LEU-based TRISO pebbles and HALEU-based TRISO-X fuel. This configuration enables the reactor core to transition to an equilibrium condition after core power density is established.
Using the reactor’s fuel handling system, the Xe-100 reactor will first cycle out the graphite ‘blanks’ for the LEU-based pebbles to establish full power and temperature The LEU-based TRISO-X fuel will then cycle out of the reactor for the HALEU-based TRISO-X fuel pebbles until the reactor operates on continuous refueling of TRISO-X fuel. This initial core load is expected to support the first approximately 5% of the plant’s life, but the initial core load is expected to generate approximately 10% of lifetime fuel revenues, with ongoing needs for additional refueling being sold through additional contracts.
Safe, established fuel form: While TRISO fuel is already an established fuel after decades of research and development, we expect our proprietary fabrication method to further differentiate our TRISO-X fuel and deliver a competitive edge in the commercial fabrication of TRISO fuel forms. We anticipate our patented and novel process will demonstrate superior quality characteristics as well as economic performance compared to historical TRISO and potential future TRISO competitors. The TRISO-X pebble fuel is a containment vessel in itself, encased in graphite, pyrolytic carbon and silicon carbide and designed not to melt due to its ability to withstand extreme temperatures. After HALEU has been encased in a TRISO pebble form, security and proliferation risks are substantially reduced. Its robust nature allows for passive safety and, we expect a small emergency planning zone for our reactors, providing additional flexibility in site design and access to non-traditional nuclear markets and customers.
Robust integrity: Our TRISO-X pebble fuel is designed not to melt due to its robust construction. This structure minimizes the requirement for the extensive use of expensive and large concrete and steel containment structures typically required in conventional reactors. TRISO-X fuel’s unique characteristics:
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At the heart of the TRISO-X fuel particle is the uranium oxycarbide kernel, which utilizes HALEU for higher energy content than the low-enriched uranium (LEU) used in conventional LWRs.
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Each fuel kernel is surrounded by four barrier layers that act in concert to support the uranium-containing kernel, moderate nuclear reactions, ensure passive safety and contain fission products.
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These particles are designed to retain their integrity during most foreseeable adverse conditions.
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The set of boundary layers act as functional containment for the radioactive fission products in the fuel kernel.
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The robust graphite pebble, about the size of a billiard ball, contains approximately 18,000 of these TRISO particles.
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Integrated fuel fabrication business: We currently manufacture TRISO-X fuel in our TRISO-X Pilot Facility in Oak Ridge, Tennessee, which has operated since 2016, and have submitted a license application to the NRC for the operation of TX-1. TX-1 will be a state-of-the-art Category II nuclear facility designed specifically for handling and processing HALEU. There are currently no commercial-scale facilities in the U.S. capable of fabricating HALEU fuel, allowing us the opportunity to address a key gap in the advanced nuclear fuel supply chain through TX-1. Planning for TX-2 is already underway, which will further expand our TRISO-X fuel production.
Path to qualification due to extensive R&D: The ability to leverage decades of prior TRISO research and development, particularly the DOE’s Advanced Gas Reactor (AGR) Fuel Development Program, provides X-energy with a well-defined pathway for fuel qualification. X-energy’s TRISO-X Pebble Fuel Qualification Methodology has been approved by the NRC and references the AGR test results as a basis for qualification. This established framework provides X-energy a streamlined path towards obtaining qualified TRISO-X fuel by the time of its first Xe-100 deployment. Based on the approved fuel qualification methodology, we are currently in the irradiation test phase and in the final stages of qualifying our TRISO-X pebble fuel.
Long-term revenues derisked: We plan to provide our Xe-100 customers with their initial fuel loads while generating additional long-term and recurring revenue streams by refueling Xe-100 reactors throughout their anticipated 60-plus year lives. Our business model is structured so that customers retain ownership and responsibility for procuring uranium and fuel feedstock, which is intended to insulate X-energy from commodity price volatility and supply chain disruptions. Further, we have no responsibility for management of spent fuel as that function is the responsibility of plant owner and operators, which roles we do not intend to participate in. We believe that our ability to achieve economies of scale through dedicated fuel fabrication facilities and our vertically integrated business model will enable us to be a low-cost provider of TRISO-X fuel, which we believe will be a key driver of customer retention and market competitiveness.
Research and Development
In addition to our core Xe-100 reactor, we continue to innovate and develop new products with our Emerging Technologies team. We are expanding our portfolio to address a broader range of energy needs and use cases beyond utility-scale power generation.
Our design team brings decades of experience from HTGR pebble-bed design programs in Germany and South Africa, combined with veterans of the DOE National Laboratories.
XENITH Microreactor
We have developed the XENITH microreactor, a compact solution designed to deliver reliable energy in locations where traditional power infrastructure is unavailable, impractical or vulnerable. XENITH is designed
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to be deployed in months and operate continuously for 20 years, delivering 3-10 MW of electricity with minimal maintenance requirements.
XENITH is not yet operational but is currently exploring commercialization opportunities. The development of the microreactor began in the Pele program through the U.S. Department of Defense, for which X-energy was awarded approximately $60 million in various contracts. Conceptual design was progressed during Pele Phase 1 and 2, and design work has continued into what is now the XENITH microreactor. The microreactor is likely to be deployed in a 5 MWe format, or as dual reactors in a 10 MWe electric format.
Like the Xe-100, XENITH is also a High Temperature Gas-cooled reactor that runs on TRISO fuel. The required fuel is expected to be in the form of compacts rather than pebbles. The expected operating temperature is 750 degrees Celsius. The value proposition is expected to be as follows:
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Scalable Power. Factory-built, transportable nuclear energy solution that prioritizes rapid site readiness and compatibility with existing infrastructure to support deployment in a wide range of locations.
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Resilient & Reliable. Provides reliable, long-term power with no required refueling over the 20-year lifetime, eliminating vulnerability to supply chain disruptions while providing 24/7 reliability.
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Tailored to the Target Market. Military, defense, and remote applications, including potential for black-starts, and remote communities that require secure, independent power.
Space Applications
Our innovative HTGR design and high-temperature-resistant fuel make a unique and compelling combination for nuclear electric propulsion, nuclear thermal propulsion and lunar surface power.
Our use of robust TRISO fuel in combination with innovative reactor designs and advanced moderator materials, all work together to increase the efficiency of the fission reaction while minimizing bulk and weight, keeping the reactor light enough for spaceflight. These characteristics have allowed us to develop viable concepts for a Fission Surface Power (FSP) reactor. This concept was studied through a joint venture award from the DOE and the U.S. National Aeronautics and Space Administration (NASA) in June 2022 to advance the design of a FSP solution.
OUR PROJECT DEVELOPMENT APPROACH
X-energy works closely with our customers throughout the project lifecycle to help avoid unexpected cost overruns in the future. In some cases, our experienced team has been able to identify equipment or design solutions to help reduce costs. We also expect to use learnings on the initial projects to bring down future costs. We believe the ability to identify cost-reduction solutions, particularly compared to traditional nuclear, gives us an advantage over other competitors who may face cost overruns or other project delays.
Traditional nuclear has consistently suffered from historical project delays and cost overruns. Vogtle units 3 & 4 were $16.0 billion+ and seven years over schedule in part because they were the first and second AP1000 reactors deployed in the U.S. While numerous factors contributed to the overruns at Vogtle units 3 & 4, core causes included an incomplete design and a fixed price agreement that led to a change in contractor after the original EPC contractor, Westinghouse, filed for bankruptcy after construction had already begun. The project subsequently was taken over by Southern Company who acted as project manager and hired Bechtel as the prime construction contractor to bring Vogtle units 3 & 4 to completion.
We are currently focused on delivering our first two projects with Dow and Energy Northwest/Amazon. We believe achieving Nth-of-a-kind scale with standard costs and schedule timelines is possible only through repeated project delivery over a large orderbook. As part of our commercialization strategy to deliver at scale, X-energy intends to support delivery of its own projects. We believe our success is dependent on leveraging economies of learning and replication, and overseeing the full development cycle of projects enables customer-centric support.
X-energy intends to partner with customers and EPC contractors to finance, build, and repeat projects. We expect to oversee projects from origination to delivery and coordinate project development. As part of our
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business model, in addition to fuel fabrication services, we intend to offer customers a suite of value-added services during development of the reactor given our expertise on regulatory, construction, procurement and other processes. Additionally, we may deploy development capital to fund early stages of future projects and to invest alongside future customers to drive an accelerated path for Xe-100 deployments.
Similar to the “design one, build many” approach that has been utilized in the oil & gas industry to deliver large-scale projects like offshore oil platforms and liquefied natural gas terminals, X-energy intends leverage its repeated order book learnings to accelerate construction timelines and reduce costs with successive deployments. Along with our project development platform, our supply chain and EPC partners are crucial to our strategy. We intend to optimize our supply chain around the modular nature of the Xe-100 to drive construction timeline acceleration. Additionally, we intend to partner with experienced EPC partners to ensure repeatable project delivery, bringing together the policy, finance and company support to help deliver our projects.
Early in the construction process, we will work with our customers to obtain the permits necessary to build and operate the projects. In determining what permits are required, we intend to engage local counsel to help us understand the requirements of state and local authorities applicable to each project. We typically intend to commence the permitting or licensing process during the early stages of development due to the length of time it typically takes to complete. For the Dow project, the CPA was docketed with the NRC in May 2025 with an 18 month review schedule. X-energy maintains a strong relationship with the NRC and works closely with customers on submitting the necessary permits. Getting an early start on permitting and licensing is important in helping to de-risk our projects, because permitting and licensing challenges or delays can have significant impacts on a project’s timeline or design, or in some cases its viability. During the permitting and licensing process, we will also seek to promote long-term community support for our projects.
As part of the permitting and licensing processes, we not only intend to support our customers in securing the permits and licenses necessary to construct and operate projects, but we also plan to work with our and our customers’ EPC and O&M contractors and partners to ensure they have plans in place to monitor permit compliance during construction and operational phases.
OUR CUSTOMERS
Dow
Dow is X-energy’s first customer to receive a reactor and is a global leader in the specialty chemicals industry, involved in the manufacturing and distribution of a wide range of chemical and plastic products. In the course of its annual operations, Dow produces over 12 million MWh of electricity and is committed to the ongoing decarbonization of its operations.
X-energy has partnered through an MPDA and CCA with Dow to provide our services in support of a FOAK deployment of four Xe-100 reactors to provide power with virtually zero direct GHG emissions and industrial steam at Dow’s UCC Seadrift site in Texas. The CCA establishes governance and commercial frameworks to advance the ARDP-supported deployment of Xe-100 reactors at Dow’s Seadrift site and guide future cooperation, including a joint steering committee with core principles of mutual cooperation and shared FOAK risk and benefit. With the support and assistance of X-energy, Long Mott Energy, LLC, a wholly owned subsidiary of Dow, filed a CPA with the NRC in March 2025 which was docketed in May 2025 for an 18-month review period with an expected review completion by late 2026 and receipt of the CPA expected in the first quarter of 2027. Initial construction can commence after receipt of the CPA.
Dow provides expertise in plant design and industrial heat as well as in the development of the Xe-100’s first plant, which will be a first-of-its-kind co-generation facility with unique heat capabilities not available in other technologies. Under the CCA, as between the parties, X-energy will own the IP related to the reactor systems, controls, software, and related nuclear plant technologies, as well as fuel technology-related IP, created by the parties for this project. As between the parties, Dow will own all of the IP related to the non-nuclear systems that turn reactor steam into electricity and run steam and water for the facility, as well as IP for equipment and processes that sit outside both the nuclear and conventional plant areas, created by the parties for this project.
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Amazon
After an extensive evaluation of potential carbon free generation solutions for its extensive data center footprint, Amazon made an equity investment in X-energy in 2024 and announced options to bring more than 5 GWe of new Xe-100 projects online across the U.S. by 2039, which assuming full exercise of these options, will represent the largest commercial deployment target of SMRs to date as of August 2025.
The first deployment under this 5 GWe total potential target is a project with Energy Northwest in central Washington. Amazon and Energy Northwest entered into a Carbon Free Development and Funding Agreement for an initial deployment of four reactors representing 320 MWe, with the potential to upsize the power capacity to 960 MWe.
X-energy has entered into commercial arrangements with Amazon, which provide for, among other things, a deployment and financing model that X-energy plans to pursue more broadly through infrastructure and utility partners. The arrangements also grant Amazon options and allocation rights intended to facilitate project development. For more information regarding our agreements with Amazon, see “Risk Factors — Our sales and profitability may be impacted by, and we may incur liabilities as a result of, terms to certain customers, our failure to meet performance guarantees under customer contracts or customer safety standards.”
Centrica
Centrica is a major provider of energy services across the U.K. and owns a 20% stake in the full fleet of operating nuclear reactors in the country. In September 2025, X-energy and Centrica signed a JDA dedicated to building and operating Xe-100 reactors in the U.K. The JDA identifies initial activities including U.K.-specific planning model translation, and execution of de-risking work packages in licensing, technology, and commercial domains, largely on a non-binding basis. Under the JDA, Centrica and the Company have the opportunity to consider options to collaborate on other Xe-100 deployments, subject to further diligence and negotiation. The announcement followed a pledge from President Donald Trump and Prime Minister Keir Starmer to work together on nuclear power and constitutes a new strategic commercial alliance to accelerate the deployment of SMRs, bringing together a leading player in delivering the U.K.’s clean energy future and the developer of the world’s most advanced nuclear technology.
The Xe-100 was selected after a significant review period by Centrica of advanced Gen IV nuclear technologies. Centrica prioritized partnership with X-energy because of the reactor’s safety and capabilities for industrial heat that Centrica sees as key to expansion in the U.K. market. The U.K. government is currently pursuing a “three-legged” approach to nuclear development, designed to ensure a diverse and resilient nuclear energy sector. Under this strategy, the first “leg” focuses on large-scale nuclear projects, such as those being developed in partnership with EDF, to provide substantial baseload power. The second “leg” supports the deployment of Gen III+ light water SMRs, with Rolls Royce’s SMR technology selected as the leading solution in this category. The third “leg” is dedicated to other small and advanced modular reactors, including HTGRs like Xe-100, which are prioritized for their potential to deliver both electricity and high-grade industrial heat, supporting decarbonization across a range of sectors.
X-energy and Centrica have identified Hartlepool as the preferred site for the first of a planned U.K. fleet of approximately six GWe (representative of 76 reactors likely deployed as 19 four-reactor configurations). A project at Hartlepool will be comprised of up to twelve 80 MWe reactors, each with the capability to provide high temperature steam for industrial decarbonization. Subject to securing appropriate permissions and licenses, the first electricity generation is expected to be in the mid-2030s.
OTHER KEY PARTNERSHIPS
Department of Energy
Through the ARDP, we are partnering with DOE and others to build the world’s first commercial scale advanced nuclear reactor. In December 2020, X-energy, initially in collaboration with Energy Northwest, was selected for a project, initially in the amount of $1.2 billion, to deliver a first-of-a-kind commercial advanced nuclear plant and TRISO-X fuel fabrication facility. This project is now being developed with Dow with
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continued financial support from the DOE on a 50/50 cost share basis. As one of only two parties selected out of many applicants for the ARDP, X-energy was recognized as having an advanced reactor technology of choice.
The cooperative agreement for the program, signed in March 2021 (the “ADRP Agreement”), provides 50/50 cost share of up to $2.4 billion of eligible costs ($1.2 billion reimbursement) through 2027, allowing X-energy to finish the remaining design, licensing, commercialization and construction of its first-of-a-kind commercial advanced nuclear plant and commercial TRISO-X fuel fabrication facility, while benefiting from decades of nuclear experience and knowledge within the DOE. The Company is constructing and will own the fuel facility subject to the government’s rights in property set forth in 2 CFR § 200.310-16 and 2 CFR § 910.360. The DOE will obtain rights to the intellectual property (“IP”) developed under ARDP Agreement consistent with typical government retained IP rights under the Bayh-Dole Act, under the Small Business Patent Waiver, and DOE regulations. The federal government retains a nonexclusive, nontransferable, irrevocable, paid-up license for its own benefit. The DOE also retains march-in rights under the ARDP Agreement which allow the government, in specified circumstances, to require the contractor or successors in title to the patent to grant a nonexclusive, partially exclusive, or exclusive license to a responsible applicant or applicants. If the patent owner refuses to do so, the government may grant the license itself. The DOE will fund a portion of the direct and indirect costs incurred for the research and development costs to develop the IP and the costs of developing and constructing both the TRISO-X fuel facility and Xe-100 demonstrator reactor. The funding is subject to future government appropriations which may not occur, and the government is able to cancel the contract at any time without incurring a substantive penalty. Dow has been named a subawardee under the ARDP in connection with their involvement with the development and construction of the demonstrator reactor.
Ontario Power Generation
In 2022, X-energy and OPG entered into a framework agreement to work exclusively with one another with respect to advanced nuclear power industrial applications in Ontario, Canada, and to co-market and advance the Xe-100 as the nuclear technology of choice for industrial applications throughout Canada. OPG will be the operator of any Xe-100 facilities that are deployed under this agreement. OPG is also an equity investor in X-energy.
Department of Defense
We have an agreement with the U.S. DOD Defense Innovation Unit (“DIU”) and the U.S. Department of the Air Force to advance the development of X-energy’s commercial microreactor in alignment with the President’s executive order to deploy advanced nuclear technologies at DOD installations to support U.S. national security. The agreement supports continued design and development for the X-energy XENITH microreactor under the Advanced Nuclear Power for Installations program, an initiative led by DIU in partnership with the Department of the Air Force. X-energy was also part of the 2019 initial selection for Project Pele to develop a prototype mobile nuclear reactor. Through these contracts, X-energy has been awarded over $60.0 million on microreactor activities including engagement with the NRC on licensing. While the period of performance for the XENITH microreactor has expired, the DOD has continued to announce initiatives that maintain interest in the microreactor program.
Under the Project Pele Agreement, the Company leads the design, analysis, testing and systems engineering needed to develop a prototype mobile nuclear reactor, and works with the DOD to help it achieve its objectives under Project Pele. The Company is paid a fixed amount for each milestone accomplished in accordance with the key objectives and milestones set out in the agreement, in addition to reimbursement of certain costs incurred. The DOD has certain rights in patents and data pursuant to the Project Pele Agreement, and may terminate the Project Pele Agreement if such termination is in the DOD’s best interest.
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OUR KEY PROJECTS
Below is a geographic overview of our three current projects, which is followed by a detailed description of each project.
![[MISSING IMAGE: map_sitenames-4clr.jpg]](https://cdn.kscope.io/66e241b40ec9a8be53aefe262681fd00-map_sitenames-4clr.jpg)
Reactor Projects
Dow’s UCC Seadrift
Dow and X-energy have entered into an MPDA to deliver the inaugural X-energy advanced nuclear reactor at Dow’s UCC Seadrift manufacturing site (“Seadrift”) in Texas. The project will be the first grid-scale advanced nuclear reactor deployment for an industrial site in North America and will help to decarbonize the operation by providing both process heat and electric power. Seadrift site production includes consumer products used every day in homes, schools, offices, hospitals, vehicles and by other industries, producing more than 4 billion pounds of materials per year across a wide variety of applications including food packaging and preservation, footwear, wire and cable insulation, solar cell membranes, and packaging for medical and pharmaceutical products.
The plant will be comprised of four reactors (320 MWe) and supply all of the site’s electricity and steam demand. Dow’s UCC Seadrift site spans around 4,700 acres and is Dow’s second largest facility in Texas. This project supports Dow’s corporate sustainability goals and is expected to reduce the site’s emissions by 440,000 MT CO2e/year.
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![[MISSING IMAGE: ph_seadriftsite-4clr.jpg]](https://cdn.kscope.io/66e241b40ec9a8be53aefe262681fd00-ph_seadriftsite-4clr.jpg)
Note: Figure is intended to represent a proposed rendering and is for illustrative purposes only.
The project benefits from the ARDP cooperative agreement with the DOE. This includes 50/50 cost share in the project. The project also includes substantial production and investment tax incentives from the Inflation Reduction Act. Through the ARDP, X-energy receives from the DOE 50% of the cost of designing the Xe-100. X-energy also receives 50% of the cost of TX-1, its first fuel fabrication facility. Finally, X-energy’s first customer to construct a reactor, Dow, will receive 50% of the cost to build the first four-pack of Xe-100s, at Seadrift, Texas, which significantly mitigates the risks of building a first of its kind advanced reactor project.
We continuously update the DOE throughout the year regarding our spending against our milestones and are currently funded through at least August 2026 through a Continuation Application.
Key Timeline Highlights of our Dow Project
![[MISSING IMAGE: fc_dowproject-4clr.jpg]](https://cdn.kscope.io/66e241b40ec9a8be53aefe262681fd00-fc_dowproject-4clr.jpg)
Development of project milestones:
— Preliminary & Final Design:
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Once Dow became our customer, our engineering design process was done in conjunction with them. The Xe-100 is in the second of three engineering design phases. Ongoing engineering and design work includes adapting to the commercial expectations of the customer, including specific seismic requirements and customer use cases. In the case of Dow, we expect some of the output of the four Xe-100 reactors to be for industrial steam for Dow’s chemical plant.
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We expect to enter into the final design phase (phase 3) according to Dow’s development process in 2027. The final design phase would culminate in a final investment decision that would lead to the beginning of major nuclear construction, though preliminary construction is expected to begin before this time. These stage gates are designed to unlock key funding tied to milestones.
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— Licensing:
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March and June 2025: With the support and assistance of X-energy, Long Mott Energy, LLC, a wholly owned subsidiary of Dow has filed a CPA with the NRC in March 2025 which was docketed in May 2025 for an 18-month review period pointing to an expected review completion by late 2026 and receipt of the CPA expected in the first quarter of 2027. The process included extensive environmental, geological, and geotechnical work such as testing of the site environment, soil, and water to help ensure that the Xe-100 plant is designed and constructed based on the site’s unique characteristics. Construction is expected to begin in 2027 after receipt of the CPA with a target Commercial Operations date in the early 2030s.
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At the appropriate time we expect our customers would submit an operating license agreement (OLA) to the NRC to be able to operate the reactor.
— Construction & readiness:
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Site construction is expected to begin in the first half of 2027 after receipt of the construction permit application from the NRC.
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Dow and X-energy have been coordinating on the financing and strategy for long lead procurement items, beginning in 2025, that are required to support the construction, commissioning and commencement of operations of the reactor expected in the early 2030s.
The agreement supports Dow’s sustainability targets. The project is set to create thousands of jobs during peak construction and hundreds of full-time, family-wage jobs during operation.
Amazon / Energy Northwest — Cascade Advanced Energy Facility
Energy Northwest is a Washington state public power joint operating agency and a premier provider of carbon-free electricity through its existing ownership of the Columbia Generating station, a 1.2 GWe nuclear power plant in Richland, WA. In 2024 Energy Northwest and Amazon entered into the Carbon Free Development and Funding Agreement for an initial deployment of four reactors representing 320 MWe at the Columbia site, with the potential to upsize the power capacity to 960 MWe enough to power the equivalent of 770,000+ U.S. homes.
![[MISSING IMAGE: ph_energyfacility-4clr.jpg]](https://cdn.kscope.io/66e241b40ec9a8be53aefe262681fd00-ph_energyfacility-4clr.jpg)
Note: Figure is intended to represent a proposed rendering and is for illustrative purposes only.
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As part of the agreement Amazon also made a direct investment in the project and the power will be available to Amazon and northwest utilities to power homes and businesses. Public power utilities will have the opportunity to purchase up to 50% of the power from the full 960 MW project. Initial site engineering work is underway. CPA is targeted for submission to the NRC by the end of 2026.
The agreement supports Amazon’s Climate Pledge commitment to reach net-zero carbon across their operation by 2040. The project is set to create 1,000-2,000 jobs during peak construction and 100-200 full-time, family-wage jobs during operation.
Key Timeline Highlights of our Amazon Project
![[MISSING IMAGE: fc_ouramazonproject-4clr.jpg]](https://cdn.kscope.io/66e241b40ec9a8be53aefe262681fd00-fc_ouramazonproject-4clr.jpg)
Development of project milestones:
— Preliminary & Final Design:
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As we finalize our design as part of the Dow project, we will integrate the site-specific design requirements at the Energy Northwest project, which is expected to generate electricity from all four reactors.
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The Energy Northwest project utilizes a progressive design build process, so the EPC was brought on board in 2025.
— Licensing:
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The Amazon / Energy Northwest CPA is targeted for submission to the NRC by the end of 2026. The construction permit is anticipated to be received in 2028, with construction commencing shortly thereafter.
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By the start of construction, engagement with the Loan Program Office is expected to be underway, and engineering work is expected to have commenced. The project is targeting Commercial Operations in the early 2030s.
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At the appropriate time we expect our customer (Energy Northwest) would submit an operating license agreement (OLA) to the NRC to be able to operate the reactor.
— Construction & readiness:
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Site construction is expected to begin in the first half of 2028 after receipt of the construction permit application from the NRC.
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Energy Northwest, Amazon, and X-energy have been coordinating on the financing and strategy for long lead procurement items, beginning in 2026, that are required to support the construction, commissioning and commencement of operations of the reactor expected in the early 2030s.
Fuel Projects
Fuel Fabrication Pilot Facility
X-energy has a TRISO-X fuel fabrication pilot facility at Oak Ridge National Laboratory. The pilot plant has been operational since 2016 and is currently producing kilogram batch quantities of TRISO-X fuel
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for development purposes. The Pilot Facility is planned to be temporarily shut down and relocated from Oak Ridge National Laboratory to property in Oak Ridge, TN for “TX-L”, which will be adjacent to the TX-1 site. The proposed TX-L will then serve as the ‘laboratory’ for future TRISO-X fuel development.
![[MISSING IMAGE: ph_pilotfacility-4clr.jpg]](https://cdn.kscope.io/66e241b40ec9a8be53aefe262681fd00-ph_pilotfacility-4clr.jpg)
TX-1
TX-1, located in Oak Ridge, Tennessee, will be the first-in-the-nation commercial advanced nuclear fuel fabrication facility. The facility will manufacture X-energy’s TRISO fuel using proprietary methods. Once complete, TX-1 will be the first Category II Fuel Fabrication Facility licensed by the NRC in the U.S. with an estimated throughput of 5 metric tons of uranium (“MTU”) per year or approximately 700,000 TRISO-X pebbles per year, enough fuel for up to 11 Xe-100 reactors.
Part of X-energy’s participation in the DOE ARDP award encompasses the Phase 2A of the TX-1 facility construction, including the completion of the core and shell of the 214 thousand square foot facility. In parallel, X-energy has received approval from the DOE to authorize an additional approximately $30.0 million for early procurement of critical long-lead equipment and materials to support the successful delivery of subsequent construction phases and ensure adherence to the overall project schedule. Lastly, TX-1 was granted an approximately $150.0 million tax credit by the DOE in recognition of its status as a U.S. FOAK advanced nuclear fuel fabrication facility, subject to the project successfully reaching certain milestones.
The facility is more than halfway through the regulatory process. The NRC review progress is on track, and X-energy has completed an internal 60% Design Review and is planning for an internal 90% Design Review in March 2026. In 2026, X-energy expects to receive a Category II license from the Nuclear Regulatory Commission to operate this facility. X-energy is using Geiger Brothers for the site development phase of the TX-1 site. Site preparation is substantially complete. Clark Construction Group has been selected to conduct the vertical construction phase (2A), which began in September 2025. Facility construction / equipment installation Phase 2B construction is set to commence mid-2026 with expected completion in 2027 for target operations beginning in the first half of 2028.
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![[MISSING IMAGE: ph_fuelorojectstx-4clr.jpg]](https://cdn.kscope.io/66e241b40ec9a8be53aefe262681fd00-ph_fuelorojectstx-4clr.jpg)
Note: Figure is intended to represent a proposed rendering and is for illustrative purposes only.
TX-2
Planning is also underway for a subsequent advanced nuclear fuel fabrication facility, which may utilize available space on the same site at TX-1 (as seen in the graphic above as “TX-2”). Future facilities modelled after TX-2 would be expected to have larger production output than TX-1 and support fuel for up to 44 Xe-100 reactors annually. The expected capacity would be 25 MTU with an anticipated 20 MTU throughput. This equates to about 2,800,000 TRISO-X pebbles per year. NRC licenses are expected for each site, so the TX-2 operating license from the NRC would be an extension of the TX-1 license that is currently underway.
![[MISSING IMAGE: ph_oakridgetn-4clr.jpg]](https://cdn.kscope.io/66e241b40ec9a8be53aefe262681fd00-ph_oakridgetn-4clr.jpg)
Note: Placement of proposed TX-1 and TX-2 sites are not to scale and should be considered illustrative
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Other
Existing Frederick Operator Training Facility
Funded partially through the ARDP, our existing Operator Training Facility in Frederick, Maryland opened in March 2023. This facility encompasses 10,447 square feet and supports several key activities related to the Xe-100 reactor program. One of the primary functions at this site is the development of a full-scale ANSI 3.5 Xe-100 simulator, which is intended to serve as a true representation of the Xe-100 plant. The simulator will incorporate all process models of Xe-100 reactors, instrumentation and control sensors and other essential elements to create an environment suitable for training and licensing Xe-100 operators prior to the initial fuel loading of the first Xe-100 reactor. This facility supports designing the Xe-100 control room and constructing a replica control room where operators will receive their training. A single Xe-100 control room is expected to be capable of managing up to twelve Xe-100 reactors.
In addition to simulator development, the Operator Training Facility is responsible for creating the operational procedures required to control the Xe-100 plant. These procedures will be developed and displayed on a computerized procedure system that we are developing, and will serve as the foundation for training materials used by Xe-100 operators. Operator training itself is conducted in a classroom environment, where our customers will be able to utilize both the simulator and our training materials to gain practical experience.
The Operator Training Facility also undertakes human factors engineering analysis, including the task analysis outlined in the NRC’s NUREG-0711, which is essential for the design of the Xe-100 control room and simulator. This analysis also helps determine the workload on Xe-100 operators, which is necessary for calculating the appropriate number of operators required in the control room.
Expanded Frederick Testing and Training Facility — XTAC
For its long-term ambitions, X-energy is developing a state-of-the-art 90,000 square foot non-nuclear test and training facility in Frederick, MD. This facility will ensure key components of the Xe-100 perform safely and reliably under real-world conditions before full-scale manufacturing and deployment. The building is anticipated to accommodate a helium test facility designed for full-scale integrated systems testing within a pressurized helium environment. Additionally, it will feature an experimental test facility dedicated to the testing and prototyping of essential reactor components and materials.
X-energy had received conditional approval from the DOE to proceed with building procurement, which has now been completed, with a 50% cost share arrangement with the DOE through the ARDP. X-energy also has the potential to receive up to $6.15 million in state and local support through job creation tax credits, conditional loans, and grants. X-energy has secured a DOE National Environmental Policy Act (NEPA) Categorical Exclusion for the building, meaning no Environmental Impact Statement or Assessment is required.
For a description of our other facilities and properties, see “Facilities Overview” included elsewhere in this prospectus.
SUPPLY CHAIN
X-energy has established an extensive, global supply chain ecosystem for the Xe-100. We have strategic and commercial partnerships that allow X-energy to leverage established players in the nuclear industry to manufacture key components, including the reactor pressure vessel & core barrel, fuel handling system, burnup measurement block, helium circulator, steam generator, fine grain reactor graphite, medium grain reactor graphite, and reactivity control & shutdown system. X-energy has signed Preferred Strategic Supplier Agreements (“PSSAs”) with key suppliers for critical Xe-100 components and systems and has built partnerships with key component providers. Throughout the process, X-energy has been working closely with suppliers in all phases of design, equipment supply, fabrication, and construction.
X-energy is differentiated in its vertically integrated fuel supply model with in-house fuel fabrication capabilities. The U.S. Government, through the DOE and HALEU Availability Program, are creating pathways toward a U.S.-based commercial enrichment supply chain with capabilities to produce HALEU domestically. X-energy received a granting of initial allocation of HALEU in April 2025. The DOE is actively
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working to provide surety of offtake to establish a domestic commercial supply of enriched uranium. Through partnerships with companies like Centrus Energy, which has already produced approximately 1 MT of HALEU to date for the DOE through its pilot cascade, the DOE is focused on creating domestic avenues for HALEU procurement.
Key components of the reactor with planned suppliers
![[MISSING IMAGE: ph_plannedsuppliers-4clr.jpg]](https://cdn.kscope.io/66e241b40ec9a8be53aefe262681fd00-ph_plannedsuppliers-4clr.jpg)
Note: Figure is intended to represent an illustrative rendering and is for illustrative purposes only.
Our Key Supply Chain Partners
We have a network of partners that enable our growth and success. These partners include:
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Curtiss-Wright. Curtiss-Wright is a leading U.S. designer and supplier of critical nuclear power plant systems, equipment, services, and spare parts to the U.S. domestic and global nuclear power industry. Following several competitive bid processes, X-energy selected Curtiss-Wright as the successful bidder for multiple Xe-100 systems. Curtiss-Wright was selected as a preferred strategic supplier to X-energy for the ARDP and subsequent Xe-100 projects in the U.S. Curtiss-Wright is an equity investor in X-energy.
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Doosan Enerbility. Doosan is a preferred strategic supplier to X-energy. Doosan is a major global manufacturer and supplier of core components of nuclear power plants, such as reactor pressure vessels, steam generators, and steam turbines. Doosan has a vertically integrated manufacturing facility in Changwon, Korea, which is capable of raw material production to final assembly of nuclear components. Doosan has manufactured and supplied 34 reactor pressure vessels and 124 steam generators globally. Doosan is an equity investor in X-energy. In December 2025, Doosan signed a Reservation Agreement with X-energy, committing to the construction of a new SMR fabrication facility to support the execution of X-energy’s more than 11 GWe commercial pipeline.
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DL E&C. DL E&C will work with X-energy to identify opportunities around the world to employ best practices to support the development and deployment of Xe-100 plants on a global scale. Founded in 1939, DL E&C has the longest business history among construction companies in Korea and has maintained a top ten Korean engineering and construction company ranking for the past 50+ years. DL E&C is the flagship company of DL Group, and has a broad range of experience in global mid/downstream energy sector engineering, procurement and construction, providing total services and solutions in more than 35 nations, focusing on a more sustainable and better future. DL E&C is an equity investor in X-energy.
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Korea Hydro & Nuclear Power. KHNP is the Korean entity that operates its nuclear and hydroelectric sector as a subsidiary of KEPCO, the majority state-owned utility. Since 1971, KHNP has successfully constructed and operated 30 nuclear power plants still in operation today, 26 in South Korea and four in the UAE. KHNP provides significant expertise in the construction of nuclear reactors. In August 2025, KHNP signed a joint compact with X-energy, Amazon, and Doosan outlining the intention to collaborate on the deployment of the Amazon order book in the U.S.
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SGL Carbon LLC. SGL is a developer and manufacturer of advanced carbon materials. X-energy and SGL have collaborated since 2015 on the qualification of NBG-18 graphite for use in the Xe-100, leveraging SGL’s experience manufacturing graphite for high-temperature gas-cooled reactors. In January 2026, SGL announced a 10-year graphite supply agreement for reactor components of X-energy’s Xe-100 SMRs, and has commenced production for the Dow Seadrift plant site as part of an initial three-year award valued at over $100 million.
COMPETITION
Our competitors include other power generation technologies, including traditional baseload power producers, other advanced nuclear technologies, renewables with or without storage, advanced energy storage, fossil fuels with carbon capture, and combinations of these technologies.
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Traditional baseload — Traditional baseload power includes natural gas, coal, oil and large-scale nuclear.
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Fossil fuels with carbon capture — Fossil fuel sources provide firm, baseload power, but require carbon capture technology to provide clean power. Carbon capture has not yet been demonstrated to be scalable to meet the market need.
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Renewables with or without energy storage — Wind and solar provide clean energy but cannot provide firm, baseload energy due to their intermittency. When paired with energy storage, they can provide a more dispatchable energy supply, but battery storage technology has not been demonstrated to be scalable or cost-effective to meet the growing market need, which demands reliability, particularly in energy-intensive applications.
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Other advanced nuclear reactors — There are several advanced reactor and SMR technologies in various stages of development, including high temperature gas-cooled reactors, molten salt reactors, fusion technologies, and advanced light water reactor designs.
REGULATORY OVERVIEW
Licensing
The regulatory pathway with the NRC for the FOAK reactor project is as follows:
![[MISSING IMAGE: fc_licensing-4clr.jpg]](https://cdn.kscope.io/66e241b40ec9a8be53aefe262681fd00-fc_licensing-4clr.jpg)
X-energy has pursued a Part 50 two-step licensing process timeline, whereby the company first seeks the Construction Permit (up to 18 months) and then seeks an Operating License (up to 18 months). This process
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gives the company flexibility to modify reactor design if warranted to achieve better economics or performance without needing to restart the licensing process. The alternative, Part 52 combined licensing process, provides a streamlined combined Construction and Operating License Application (“COLA”). However, recent submissions under Part 52 have resulted in application re-submissions caused by changes in design on NRC findings or insufficient initial applications.
X-energy expects the regulatory review timeline to shrink materially as the NRC’s familiarity with the Xe-100 design increases. Additionally, the current U.S. government is focused on legislation to streamline permitting, and the current Administration has issued several Executive Orders to streamline licensing at the NRC, accelerate advanced reactor deployment at the DOE and DOD sites for national security and AI/data-center needs, overhaul the domestic nuclear fuel cycle, and strengthen the U.S. nuclear industrial base. Further, once X-energy achieves NOAK status and is no longer concerned with design changes impacting the regulatory design, a COLA process would further abbreviate the regulatory approval timeline. X-energy is developing novel strategies that are anticipated to enable the NRC regulatory review process to become as short as 6 months.
Potential Tax Credits per Standard Configuration of Xe-100 Reactors for Customers
The One Big Beautiful Bill was signed into law in July 2025, maintaining the Clean Electricity Production Tax Credit (§45Y) and Clean Electricity Investment Tax Credit (§48E). These credits remain available to certain new nuclear facilities that begin construction prior to 2034 before being phased out over three years. The OBBBA also expanded the 10% Production Tax Credit (§45Y) adder for nuclear facilities that are located in “energy communities” which includes metropolitan areas with significant direct employment related to the advancement of nuclear power. Additionally, the U.S. House of Representatives’ FY26 appropriations bill the Energy and Water Development and Related Agencies Appropriations Act, passed by the House of Representatives on January 8, 2026, includes $1.78 billion in total resources for nuclear energy, including funding to advance production of HALEU and to repurpose previously appropriated funds to accelerate advanced reactor and small modular reactor demonstration projects. This financial support demonstrates the current U.S. Congress’s focus on accelerating the nuclear, particularly SMR, sector and will fundamentally enhance economics and solidify advanced nuclear reactors as an attractive power alternative. As of the time of this prospectus, the Senate has yet to act on the FY26 appropriations bill.
Clean Electricity Production Tax Credit (§ 45Y)(1), (2), (3)
Up to around $83.0 million of potential tax credits to a customer per four 80 MWe reactors (used to produce electricity) per year for 10 years, adjusting each year for inflation
![[MISSING IMAGE: fc_productiontax-4clr.jpg]](https://cdn.kscope.io/66e241b40ec9a8be53aefe262681fd00-fc_productiontax-4clr.jpg)
How it works:
Tax credit of 1.5¢/kWh adjusted annually for inflation (3.00¢/kWh in 2025) of electricity produced and sold for up to 10 years after the facility is placed in service
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+ 10% boost if reactor is in either a designated “nuclear energy community” or “energy community” (e.g., former coal mine or brownfield site)
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+ 10% boost if reactor constructed with domestic iron and steel and a minimum of 40% (minimums increase over time) domestic manufactured products (or an exception applies)
= up to around 3.60¢/kWh total credit
(1)
Eligibility requirements: Applies to facilities used for the generation of electricity placed in service after
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December 31, 2024 and facilities’ whose “greenhouse gas emission rate,” do not exceed zero and whose electricity is produced in the U.S. and sold to “unrelated persons;” and facilities that meet “prevailing wage” and “apprenticeship” requirements.
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Projects that start construction on or prior to July 4, 2026, after the following “applicable year” are subject to a four-year phase-out beginning the later of (i) the date that the U.S. Secretary of Energy determines that annual greenhouse gas emissions from electrical generation is equal to or less than 25% of emissions in 2022 or (ii) 2032.
b.
Projects that begin construction after July 4, 2026, are subject to a four-year phase-out beginning in 2032.
c.
Projects that begin construction after December 31, 2025, may not receive material assistance from certain prohibited foreign entities in constructing such facilities.
(2)
Hours in a year multiplied by 1,000.
(3)
Rates as of 2025. Tax credit is adjusted annually based on inflation.
U.S. Clean Electricity Investment Tax Credit (§ 48E)(1), (2)
Up to around $50 of potential illustrative tax credits to a customer for every $100 of cost born per four 80 MWe reactors purchased, claimed in the year when the plant is put in service
![[MISSING IMAGE: fc_cleanelectricity-4clr.jpg]](https://cdn.kscope.io/66e241b40ec9a8be53aefe262681fd00-fc_cleanelectricity-4clr.jpg)
How it works:
Tax credit of 30% of the initial capital cost in a facility
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+ 10% boost if reactor is in an “energy community” (e.g., former coal mine or brownfield site)
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+ 10% boost if reactor constructed with domestic iron and steel and a minimum of 40% domestic manufactured product (or an exception applies)
= up to 50% tax credit on upfront capital costs
(1)
Eligibility requirements: Applies to facilities used for the generation of electricity placed in service after December 31, 2024. The facility’s “greenhouse gas emission rate” cannot exceed zero and must meet “prevailing wage” and “apprenticeship” requirements. Credits are subject to recapture if eligibility requirements are not maintained or if the facility is sold.
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Projects that start construction on or prior to July 3, 2026, after the following “applicable year” are subject to a four-year phase-out beginning the later of (i) the date that the U.S. Secretary of Energy determines that annual greenhouse gas emissions from electrical generation is equal to or less than 25% of emissions in 2022 or (ii) 2032.
b.
Projects that begin construction on or after July 4, 2026, are subject to a four-year phase-out beginning in 2032.
c.
Projects that begin construction after December 31, 2025, may not receive material assistance from certain prohibited foreign entities in constructing such facilities.
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(2)
Subject to diligence and IRS rulemaking process on expense eligibility for investment tax credit. X-energy assumption not explicitly included in IRA; similar provisions have been included in prior renewables tax credit programs.
Potential Tax Credits Related to Construction of Fuel Fabrication Facility TX-1
Qualifying Advanced Energy Project Credit (§ 48C)
The Qualifying Advanced Energy Project Credit (§ 48C) was initially created under the American Recovery and Reinvestment Act (2009) and later expanded by the Inflation Reduction Act (“IRA”) of 2022. The program creates a qualifying investment tax credit for facilities that manufacture clean energy equipment, nuclear fuel or related supply chain technologies. In March of 2024, TRISO-X was awarded around $150.0 million investment tax credit for the construction of its first purpose-built commercial-scale fuel fabrication facility, TX-1, in Oak Ridge, TN. Upon meeting certification and ‘placement in service’ qualifications, the credit will be applied against the company’s federal income tax liability or is eligible to be transferred to an unrelated 3rd party per IRC § 6418 that equals 30% of the eligible capital investment costs, up to allocated award, in construction and equipping of the TX-1 facility.
GOVERNMENT AND REGULATION
Policymakers and industry leaders increasingly recognize that nuclear, and particularly advanced nuclear, will be a key component of the clean energy transition. Growing energy demand, paired with enduring considerations around managing longer-term carbon risk, creates a clear need for what nuclear can offer: carbon-free, consistent baseload energy generation. According to the IEA, fossil fuels currently supply around 60% of global electricity generation, and the IEA projects that, under the most likely scenario, global electricity demand could increase by more than 50% by 2050. As such, nuclear is expected to play a significant role in virtually every credible pathway to achieving net-zero.
While renewables have made and continue to make a meaningful contribution to this transition, they lack several key advantages that advanced nuclear offers; specifically, the ability to deliver land-efficient and readily dispatchable energy. Further, advanced nuclear offers expanded use cases, such as industrial heat, while having lower capital costs, geographic flexibility, simplified operations and substantial safety improvements over legacy nuclear plants. We believe these factors uniquely position advanced nuclear as a central component of the global energy system moving forward.
Nuclear energy has received significant federal- and state-level support in the U.S. in recent years. Currently, about half of U.S. states have, or are considering, policies to support advanced nuclear. Several have also adopted binding deadlines — via legislation, executive orders, or administrative actions — to mandate decarbonization of energy purchased, sold or generated within their borders.
At the U.S. federal level, support for advanced nuclear power has been steady since the adoption of the Nuclear Energy Innovation Capabilities Act in 2018. Since then, billions of dollars have been allocated to nuclear energy in recent significant energy-related legislation, including in the Nuclear Energy Innovation and Modernization Act of 2019, the Infrastructure Investment and Jobs Act of 2021, the Inflation Reduction Act in 2022, and the Accelerating Deployment of Versatile, Advanced Nuclear for Clean Energy Act in 2024, all passed with strong bipartisan and bicameral support.
Similarly, U.K. and Canada policymakers have also expanded support of advanced nuclear. In December 2021, the U.K. government designated HTGRs as the technology focus for its Advanced Modular Reactor (“AMR”) demonstration program, citing their potential to contribute to net-zero goals, ability to produce high-temperature industrial heat, relatively high technical maturity, and the proven safety record of the U.K.’s second-generation Advanced Gas-cooled Reactors.
United States
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Nuclear Energy Innovation Capabilities Act (“NEICA”). Signed into law in September 2018, NEICA directs the DOE to prioritize research, development, and demonstration of advanced nuclear reactor technologies, authorizes the creation of a National Reactor Innovation Center to facilitate private
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sector access to DOE facilities for testing and demonstration, and promotes public-private partnerships to accelerate the commercialization of innovative nuclear energy solutions.
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Nuclear Energy Innovation and Modernization Act (“NEIMA”). Signed into law in January 2019, NEIMA directs the NRC to modernize its licensing processes for advanced nuclear technologies, establishes a new fee structure to ensure more predictable and transparent costs for applicants, and requires the NRC to develop a framework for licensing advanced reactors.
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Infrastructure Investment and Jobs Act (“IIJA”). Signed into law in November 2021, the IIJA provides $65.0 billion for power and grid investments, including grid reliability, resiliency, and clean energy technologies such as carbon capture, hydrogen and advanced nuclear. The IIJA appropriated $2.477 billion funding for the two ARDP demonstration projects (of which X-energy is one), following its creation in the Energy Act of 2020.
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Inflation Reduction Act. Signed into law in August 2022, the IRA appropriated $700.0 million to support the transportation and availability of HALEU fuel and increased DOE’s loan guarantee authority to $250.0 billion, both measures that will support the acceleration of reactor deployment and improve projects economics.
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Accelerating Deployment of Versatile, Advanced Nuclear for Clean Energy Act (ADVANCE ACT). Signed into law in 2024, this historic nuclear energy package brings the U.S. closer to its goals of energy independence and international market leadership. The Act includes NRC licensing reform, opens the door to foreign investment, and directs the NRC to develop a program to enhance the agency’s preparedness and coordination in qualifying and licensing advanced nuclear fuels.
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Recent Executive Orders. The current Administration unveiled four Executive Orders on May 23, 2025 directing federal agencies to streamline licensing at the NRC, accelerate advanced reactor deployment at the DOE and DOD sites for national security and AI/data-center needs, overhaul the domestic nuclear fuel cycle, and strengthen the U.S. nuclear industrial base.
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“Reforming the Nuclear Regulatory Commission” which directed a reorganization of the current Nuclear Regulatory Commission structure to promote faster processing of license applications and mandated an 18-month review period for a decision on an applications to construct and operate new reactors (including advanced nuclear reactors).
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“Reinvigorating the Nuclear Industrial Base” seeks to reduce U.S. dependence on foreign sources of nuclear fuel by funding a buildout of domestic supply chains to support the current nuclear fleet and an expansion of production by four times by 2050 with an emphasis on establishing a domestic nuclear fuel cycle — including uranium enrichment, restart, completion, uprates, or construction of reactors; and expanding the nuclear energy workforce.
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“Deploying Advanced Nuclear Reactor Technologies for National Security” defines AI as a national security objective and the order sets a priority for the DOE and the DOD to work with private industry to accelerate deployments of advanced nuclear technology to power AI. Key goals include designating DOE sites appropriate for advanced nuclear reactors within 30 months, deploying an advanced nuclear reactor within three years at a domestic military installation and releasing 20 MTU of HALEU for advanced reactor design use at DOE sites.
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“Reforming Nuclear Reactor Testing at the Department of Energy” finds the design, construction and operation of test reactors for research purposes and that do not produce commercial power to fall under the purview of the DOE and directs DOE to streamline environmental reviews and expedite qualified test reactors for operation at DOE-owned or controlled facilities within two years of an application.
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One Big Beautiful Bill Act. Signed into law in July 2025, the OBBBA is a comprehensive tax and spending package that makes permanent many provisions of the 2017 Tax Cuts and Jobs Act, while introducing new tax policies and restructuring others. The OBBBA generally maintains the Clean Electricity Production Tax Credit and Clean Electricity Investment Tax Credit for nuclear power that were added by the IRA but subjects it to a phase-down schedule that begins for projects that commence construction after 2033. Projects beginning construction in 2034 and 2035 will still qualify for tax credits but with a 75% and 50% credit value, respectively. These projects must meet the traditional
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continuity test, which requires placement in service by the end of the fourth year after the end of the year in which construction starts, or else demonstrate that construction was continuous based on the facts. The OBBBA also provides an expanded 10% tax credit adder definition for the PTC for nuclear facilities located in designated “energy communities” and authorizes additional credit subsidies and loan guarantee authority to support the deployment of advanced nuclear technologies.
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Additionally, through the OBBBA, the U.S. Congress reinforced earlier legislation focused on the acceleration of environmental review requirements under NEPA for project proponents that pay certain fees. Further, DOE amended its NEPA guidelines further to set page limits, foster greater collaboration between the agencies, and expand the scope of cases that qualify for a shorter and streamlined review process because the projects have a limited environmental impact (such as siting new small-scale projects on existing brownfield or DOE sites). NRC has also begun the process of updating its NEPA guidelines, which are anticipated to similarly streamline project reviews.
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Other Legislative Support Provisions under Consideration in the U.S. Congress. Additionally, the U.S. House of Representatives’ FY26 appropriations bill the Energy and Water Development and Related Agencies Appropriations Act, passed by the House of Representatives on January 8, 2026, includes $1.78 billion in total resources for nuclear energy, including funding to advance production of HALEU and to repurpose previously appropriated funds to accelerate advanced reactor and small modular reactor demonstration projects. This financial support demonstrates the current U.S. Congress’s focus on accelerating the nuclear, particularly SMR, sector and will fundamentally enhance economics and solidify advanced nuclear reactors as an attractive power alternative. As of the time of this prospectus, the Senate has yet to act on the FY26 appropriations bill.
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Several States Showing Strong Commitment to SMR Development. With increasing electricity demand and a desire to attract AI & data centers, there has been significant movement at the state level to incentivize the deployment of nuclear across U.S. states. Many have shown strong commitment towards developing advanced nuclear technologies, including SMRs, and putting in place the necessary legislation to facilitate nuclear power build-out in their states. For example:
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Texas: Enacted House Bill 14 to create the Texas Advanced Nuclear Deployment Office and established the Texas Advanced Nuclear Development Fund, which provided an initial $350.0 million to support both development and construction of advanced nuclear reactors.
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Tennessee: Created the Tennessee Nuclear Energy Fund to expand nuclear development and manufacturing ecosystem for the state of Tennessee, which included an initial $50.0 million which has increased to $70.0 million by additional $10.0 million installments in FY25 and FY26.
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Washington: Enacted a clean electricity standard in 2019 which would eliminate coal generation by 2025 and mandate 100% clean energy by 2045, including nuclear; provided $25.0 million to Energy Northwest in support of the utility’s application to the DOE’s Loan Programs Office.
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Maryland: Established greenhouse gas emissions reduction targets and formally recognized the critical role that nuclear energy plays in the state’s clean energy generation profile in 2022; in 2025, the state passed the Next Generation Energy Act which establishes a framework that includes incentives aimed at advancing nuclear energy generation across the state.
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Indiana: Signed a new law in 2025 that supported the development of small modular reactors in Indiana, including a 20% Investment Tax Credit for SMR manufacturing and allowing utilities to seek preapproval and timely recovery for project development costs related to nuclear energy.
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Virginia: Established the Virginia Nuclear Energy Consortium (VNEC) to sustain the state’s leadership in nuclear energy through interdisciplinary business development, research, and training related to nuclear energy; passed legislation allowing investor-owned electric utilities to accelerate cost recovery for project development of SMRs.
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Louisiana: Established the Louisiana Advanced Nuclear Competitive Edge (LANCE) Strategic Framework, authorized by the Public Service Commission, to position the state as a leader in advanced nuclear reactors, particularly SMRs.
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West Virginia: Repealed its ban on construction of nuclear power plants, removing legal constraints that previously blocked new nuclear capacity, including SMRs.
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Illinois: Lifted or partially eased its moratorium on new nuclear plants to allow SMRs (specifically reactors up to around 300 MW) beginning in 2026, while putting in place needed regulatory and safety frameworks.
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New York: Launched a Master Plan for Responsible Advanced Nuclear Development, backed by a blueprint from NYSERDA. The plan includes efforts to deploy advanced nuclear technology as well as development of early site permits for advanced reactors at locations like Nine Mile Point.
Canada
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Clean Technology Investment Tax Credit. On June 20, 2024, Bill C-59 received royal assent and enacted legislation to implement the clean technology investment tax credit (“CT ITC”). The CT ITC is a 30% refundable investment tax credit applicable to the capital cost of clean technology property in Canada including certain small modular reactor equipment. The CT ITC is applicable in respect of the cost of eligible property that was acquired and became available for use on or after March 28, 2023. The CT ITC rate is reduced to 15% for eligible property that becomes available for use in 2034, and the CT ITC is not available for property that becomes available for use after 2034. If certain labor conditions are not satisfied then the tax credit rate is reduced to 20%. The CT ITC is available in respect of certain small modular reactor equipment that is part of a system that has a gross-rated generating capacity not exceeding 300 MWe or an energy balance equivalent gross rated generating capacity of electricity or heat equivalent of 1,000 MWt.
United Kingdom
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In 2025, the U.K. government announced its intent to create a new ‘Golden Age of Nuclear’ in the U.K. and encourage private sector investment in next-generation nuclear technologies. It implemented significant reforms to accelerate the deployment of small modular reactors (SMRs) and Generation IV advanced modular reactors (AMRs) including High Temperature Gas-cooled Reactors (HTGRs). Planning reforms were launched to expand eligible sites for SMRs beyond the previous eight locations to cover all of England and Wales, supporting growing energy demand from data centers and heavy industry. The Government declared it would offer value-for-money project equity and debt provision from the National Wealth Fund, and financial risk mitigation and revenue support mechanisms, negotiated with the DOE Security and Net Zero. A regulatory task force was set up to shorten nuclear licensing and consenting timelines, and the U.S. and U.K. Governments adopted the Atlantic Partnership for Advanced Nuclear Energy, including a regulatory co-operation agreement designed to achieve efficiencies through collaboration on assessment data.
Nuclear Safety Regulation
The commercial nuclear industry is heavily regulated worldwide. Regulatory approval is required for the design, construction and operation of every nuclear plant, as well as the fuel facilities that supply them. Regulations are designed to ensure protection of people and the environment and typically address: (1) design safety and robustness against internal hazards (e.g., component failures, fires) and external hazards (e.g., earthquakes and extreme weather), and (2) environmental impacts of construction and operations (e.g., water use, preservation of historical sites, animal and plant species). Although regulations are country-specific, regulators often collaborate when a design is deployed in multiple jurisdictions.
X-energy’s licensing strategy has two goals: (1) obtain approval of a reactor project deploying X-energy’s technology within the shortest possible time, through early regulatory engagement and high-quality applications; and (2) maintain a common Xe-100 design across markets.
After several years of pre-application engagement, in March 2025, Long Mott Energy, LLC, a wholly owned subsidiary of Dow, submitted a construction permit application to the NRC for a proposed advanced nuclear project deploying four Xe-100 reactors at a Dow plant in Seadrift, Texas. Citing the completeness and
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quality of the application, and the effectiveness of pre-application engagements, the NRC published an 18-month review timeline for the project and began a concurrent environmental assessment. All current pre-licensing work is conducted and submitted by X-energy in order to de-risk future construction permit and operating license applications to the NRC, whether ARDP funded or not, that will be submitted by our customers, the plant owners.
Environmental review under the National Environmental Policy Act is required for federal actions, including approval of the construction permit application. During the environmental review, the NRC consults with collaborating federal agencies, as well as state, local, and tribal authorities, to ensure the relevant parties are aware of and acknowledge the licensing actions being considered. The public is also granted opportunities for comment. In certain cases, individual states may have additional environmental review requirements related to the construction and operation of a nuclear power plant. The environmental review requires the NRC to consider any state, local and tribal stakeholders. In addition to NRC approvals, other federal and state government permits and authorizations will be required to construct and operate the Long Mott Generating Station facility, including those discussed below.
Environmental, Occupational Health and Safety, and Other Regulations
X-energy is also subject to regulations regarding nuclear material safeguards, non-proliferation restrictions, liability insurance regimes, and various other matters. Both we, for our production facilities, and customers purchasing our reactors must obtain a variety of permits, licenses, and insurance for the jurisdiction where the facility will be located. We and customers purchasing our reactors are subject to stringent and complex federal, state, local and international laws and regulations governing the discharge of materials into the environment or otherwise relating to protection of worker health, safety and the environment. Compliance with all of these laws and regulations may expose us to significant costs and liabilities and cause us to incur significant capital expenditures in our operations. Any failure to comply with these laws and regulations may result in the assessment of administrative, civil and criminal penalties, imposition of remedial obligations, and the issuance of injunctions delaying or prohibiting operations. Private parties may also have the right to pursue legal actions to enforce compliance as well as to seek damages for non-compliance with environmental laws and regulations or for personal injury or property damage. In addition, the trend in environmental regulation is to place more restrictions on activities that may affect the environment, and thus, any changes in, or more stringent enforcement of, these laws and regulations that result in more stringent and costly pollution control equipment, the occurrence of delays in the permitting or performance of projects, or waste handling, storage, transport, disposal or remediation requirements could have a material adverse effect on our operations and financial position.
Our business and the business of customers purchasing our SMRs must obtain required permits, licenses and insurance for the jurisdiction where the facility will be located. In the U.S., we and our customers are subject to NRC regulation and licensing as well as other federal and state radioactive materials licensing. For example, we are required to receive, and have submitted an application for, a Special Nuclear Material Licenses from the NRC for the possession and use of enriched uranium and will be required to receive a Specific and General Radioactive Material License from the State of Tennessee for our TX-1 facility.
Development and operation of our TX-1 facility, the Long Mott Generating Station, our other facilities and our customers’ other facilities are also subject to federal, state and local regulation, including under the Clean Water Act, Clean Air Act and Occupational Health and Safety Act, and required to obtain and maintain permits such as National Pollutant Discharge Elimination System (NPDES) Permit for Storm Water Discharges from Construction Activities and local construction permits. Furthermore, some environmental laws impose substantial penalties for noncompliance, and others, such as the federal Comprehensive Environmental Response, Compensation, and Liability Act (“CERCLA”), the Resource Conservation and Recovery Act (“RCRA”), or similar state laws, may impose strict, retroactive and joint and several liabilities for the remediation of releases of hazardous substances. Stated differently, liability under CERCLA, RCRA or similar state and local laws, may be imposed as a result of conduct that was lawful at the time it occurred or for the conduct of, or conditions caused by, prior operators or other third parties. Failure to properly handle, transport, store or dispose of hazardous materials or otherwise conduct our operations in compliance with RCRA and other EHS laws or similar state and local laws could expose us to liability for governmental penalties, cleanup costs and civil or criminal liability associated with releases of such materials into the
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environment, damages to property, natural resources and other damages, as well as potentially impair our or our customers’ ability to conduct our operations.
Finally, siting, cost recovery, interconnection and other state and federal issues for power plants of any type are also often subject to occasionally lengthy approval processes by state utility regulators, independent transmission system operators, and FERC approvals.
Our compliance with these and other laws, regulations, and contractual commitments may be onerous and could, individually or in the aggregate, increase our cost of doing business, impact the financial viability of our business model, limit our ability to pursue certain business practices or offer certain products and services, cause us to change our business models and operations, affect our competitive position relative to our peers, and/or otherwise harm our business, reputation, financial condition, and operating results.
We also cannot be assured that future events, such as changes in existing laws or enforcement policies, the promulgation of new laws or regulations or the development or discovery of new facts or conditions adverse to our operations will not cause us to incur significant costs. While we are confident in our compliance with current environmental regulations, we acknowledge the potential for policy shifts that could impact our operations. On January 20, 2025, President Trump issued a series of executive orders and memoranda signaling a shift in environmental and energy policy in the U.S., including the revocation of approximately 80 Biden-era executive orders related to public health, the environment, climate change and climate-related financial risks. President Trump also declared a “national energy emergency,” directing agencies to expedite conventional and nuclear energy projects. While the extent of the current Administration’s changes to the environmental regulatory landscape in the U.S. is unknown at this time, it is possible that additional changes in the future could impact our results of operation and those of our customers.
Additional information regarding certain risks related to government regulations is included in “Risk Factors — Risks Relating to Compliance with Law, Government Regulation and Litigation.”
Export Controls
Our business is subject to and must comply with stringent U.S. import and export control laws, including DOE regulations under 10 CFR Part 810 (governing the export of nuclear technology and technical assistance by U.S. persons); NRC regulations under 10 CFR Part 110 (governing import and export of nuclear hardware, equipment, and materials); and Export Administration Regulations issued by the Bureau of Industry and Security within the U.S. Department of Commerce (covering “dual-use” items and associated foreign assistance).
Export control regulations safeguard U.S. national security, support foreign policy objectives, and uphold nonproliferation commitments. Governmental authorizations (e.g., DOE Part 810 approval) may be required before we export technology, equipment, materials, or services, or collaborate with foreign entities. X-energy maintains an extensive export control program to ensure compliance.
The U.S. government agencies responsible for administering the nuclear export control regulations have a degree of discretion in interpreting and enforcing these rules, and in approving, denying, or conditioning authorizations. Their decisions are also shaped by multilateral export control regimes and geopolitical developments.
FACILITIES OVERVIEW
We own or lease facilities and property in the following geographic locations:
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Rockville, Maryland — The following facilities are located in Rockville, Maryland:
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X-energy’s corporate headquarters consists of 39,000 square feet and houses the Xe-100 engineering teams performing engineering, design, operations, testing, code development, quality assurance, licensing and project management. In addition, the Rockville facility houses the executive management team as well as accounting, marketing, human resources, procurement and legal staffs.
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X-energy also holds a lease with a third-party for offices consisting of 49,000 square feet in Rockville, Maryland that is expected to house the teams named above beginning in 2026.
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Frederick, Maryland — The following facilities are located in Frederick, Maryland:
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The Operator Training Facility — This facility became operational in October 2023 and consists of 10,447 square feet and houses the following activities:
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Xe-100 Simulator Development — This activity includes the development of a full-scale ANSI 3.5 Xe-100 simulator that is a true representation of the Xe-100 plant. The simulator model will include all process models of Xe-100 reactors, instrumentation and control sensors and other elements to provide an environment to train and license Xe-100 operators before the first Xe-100 reactor’s fuel is loaded. This activity also includes the design of the Xe-100 control room and the construction of a replica control room where the operators will be trained. It is expected that a single Xe-100 control room will be sufficient to control up to twelve Xe-100 reactors.
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Xe-100 Operator Procedure Development — This activity includes the development of the operational procedures needed to control the Xe-100 plant. The procedures will be developed then displayed on a “computerized procedure system” that X-energy will be developing, and will be used to create training material for Xe-100 operators.
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Xe-100 Operator Training — This activity includes training Xe-100 operators in a classroom environment. Students will use the simulator and X-energy training materials.
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Human Factors Engineering Analysis — This activity includes the task analysis in NRC’s NUREG-0711 needed for the Xe-100 control room and simulator design, among other analyses. This activity is also necessary to determine the workload on Xe-100 operators to calculate the necessary number of operators in the control room.
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The Frederick Testing Facility (to be known as “XTAC” or “X-energy Technology Advancement Center”) — This facility was purchased in July 2025 and consists of 90,000 square feet which will be used for office space, major component testing, machining and manufacturing studies, and training collateral, including the following:
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eXperimental Test Facility (“XTF”) — The XTF is expected to begin testing in 2026. It will allow for bench-scale and fractional scale testing of our first-of-a-kind components and technologies, allowing for rapid refinement of designs. Specifically, the XTF will be testing the steam generator interfaces, the reactor cavity cooling system, components for the fuel handling system and mechanical properties of the fuel pebbles, among other systems.
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Machine Shop — The machine shop is expected to begin testing in 2026. It will allow for rapid prototyping of critical components in the reactor. Specifically, the machine shop will be manufacturing fuel handling system components and main system components and machining graphite blocks, among other systems.
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Helium Test Facility (“HTF”) — This testing facility is expected to begin tests in mid-2027. It will allow for testing of our first-of-a-kind technologies in a reactor-simulating high-pressure, high temperature helium environment. The HTF will test the fuel handling system, the helium circulator, and the RODS, among other systems.
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Training Facility — The facility will house training facilities for operators, simulators, chemistry, security and other reactor support staff. The location will also allow for curriculum design. The facility will begin construction in 2026 and be built over to support Operational Readiness.
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Office space — The facility will feature 22,000 square feet of office space, used as offices and conference rooms for facility staff and visiting employees and guests.
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Oak Ridge, Tennessee — The following facilities and sites are located in Oak Ridge, Tennessee:
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Oak Ridge National Lab (“ORNL”) — This space located within ORNL is called the TRISO-X Pilot Facility, which houses a single commercial scale TRISO-X fuel fabrication line and can produce HALEU-bearing fuel. It has been used to test new fabrication processes, leading to 13 issued U.S. patents, and five provisional U.S. patent applications. We anticipate winding down operations at this space through first half of 2026.
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Lafayette Road Facility — The facility began operations in January 2023. It consists of approximately 42,000 square feet and houses TRISO-X staff, performing primarily NRC licensing engagement, support for the deployment of the TF3 and process equipment design.
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Commercial Fuel Fabrication Facility (TX-1) — Our first fuel facility began vertical construction in September 2025. Once operational, the facility is expected to be North America’s first purpose-built commercial advanced nuclear fuel fabrication facility. This site is 110 acres, and is part of a former DOE site known as Horizon Center Industrial Park.
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Apollo Emory Valley Site — Leased for storage space that we anticipate moving in Spring 2026.
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Planned TX-L site — Known as ‘Area 7’, this site is on adjacent land to our planned TX-1 location.
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Toronto, Canada — X-energy’s Toronto office space houses staff and is the headquarters of the wholly owned subsidiary, X-Energy Canada, Inc.
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Warrington, England — X-energy’s Warrington office space houses staff and is the headquarters of the wholly owned subsidiary, X-Energy UK.
The company believes the locations of its facilities provide it with unique access to the NRC, U.S. government partners and customers, and the DOE’s extensive ORNL lab facilities and personnel, along with being attractive locations within some of the most well-educated metropolitan corridors in North America.
The existing facilities accommodate current operating needs, and the company will expand current facilities as needed to accommodate a growing workforce as it moves closer to deploying the Xe-100 and associated services.
INTELLECTUAL PROPERTY
We rely on a combination of patent and trade secret protection laws, as well as contractual restrictions in our agreements with our employees, contractors, consultants and third parties with whom we have relationships, to protect and enhance the proprietary technology, inventions and improvements that are commercially important to our business. We also rely on trademark laws to protect our brands.
Our policy is to protect our competitive position by, among other methods, filing patent applications in the U.S. and other jurisdictions, related to our proprietary technology, inventions, improvements and products that are material to our business. We also rely on our trade secrets and know-how relating to proprietary technology, inventions, improvements and products as well as certain innovation and in-licensing opportunities to develop, strengthen and maintain our competitive position in the field; however, such rights can be difficult to protect and provide us with limited protection. We take steps to protect and preserve our trade secrets and know-how by employing various methods, including entering into confidentiality, non-disclosure and non-compete agreements with certain of our employees and third parties, including our vendors, contractors and potential business partners, to protect our intellectual property and proprietary information.
As of the date of this prospectus, we own approximately 13 issued U.S. patents, 14 pending U.S. patent applications, two U.S. trademark registrations and two U.S. trademark applications. The issued U.S. patents have expiration dates between 20 and 20 . Of those approximately 13 issued U.S. patents, of them cover certain aspects of our reactor and fuel technology. We also own issued patents and pending patent applications in each of , and .
EMPLOYEES AND HUMAN CAPITAL
As of January 1, 2026, we have a highly educated workforce of 889 employees, of whom 312 have master’s degrees and 107 have Ph.Ds. Our employees are located across 40 different states and three countries. We are dedicated to our corporate goal of changing the world through innovative and implementable energy solutions.
Due to the highly specialized nature of our business, we need to hire and train skilled and qualified personnel to design, build and operate our state-of-the-art equipment, and to perform a broad range of services to support our company and our customers. Our success as a company depends on our ability to attract, develop and retain people with highly technical and specialized expertise who are dedicated to
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consistently performing quality work and, for some of our positions, can obtain a security clearance. We are dedicated to promoting the health, welfare and safety of our employees. We strive to treat all employees with dignity and respect and provide them with fair, market-based, competitive and equitable compensation. We aim to recognize and reward the performance of our employees in line with our pay-for-performance philosophy and provide a comprehensive suite of benefit options that enables our employees and their dependents to live healthy and productive lives. Moreover, we aim to foster an environment where individuals feel a sense of belonging and can achieve their highest potential, regardless of personal background. We are an equal opportunity employer and work to create an inclusive environment, built on a foundation of compliance with applicable civil rights laws.
Safety in our workplaces is paramount. We take measures to prevent workplace hazards, encourage safe behaviors and enforce a culture of continuous improvement to foster processes that help us eliminate incidents and injuries and comply with applicable health and safety laws.
LEGAL PROCEEDINGS
From time to time, we may be subject to various claims, lawsuits and other legal and administrative proceedings that may arise in the ordinary course of business. Some of these claims, lawsuits and other proceedings may range in complexity and result in substantial uncertainty; it is possible that they may result in damages, fines, penalties, non-monetary sanctions or relief. We currently do not have any claims, lawsuits or proceedings against X-energy that, individually or in the aggregate, would be considered material to our business or likely to result in a material adverse effect on our future operating results, financial condition or cash flows.
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BOARD OF DIRECTORS AND MANAGEMENT OF X-ENERGY
The table below sets forth information about the executive officers and directors that are expected to be in place upon consummation of this offering. With respect to our directors, each biography contains information regarding the person’s service as a director, business experience, director positions held currently or at any time during the past five years, information regarding involvement in certain legal or administrative proceedings and the experience, qualifications, attributes or skills that caused our board of directors to determine that the person should serve as a director of the Company.
The initial Class I directors shall serve for a term expiring at the first annual meeting of stockholders. The initial Class II directors shall serve for a term expiring at the second annual meeting of stockholders; and the initial Class III directors shall serve for a term expiring at the third annual meeting of stockholders. At each annual meeting of stockholders beginning with the first annual meeting of stockholders, the successors of the class of directors whose term expires at that meeting shall be elected to hold office for a term expiring at the third annual meeting of stockholders to be held following their election. Each director in each such class shall hold office until such director’s successor is duly elected and qualified, subject to such director’s earlier death, resignation or removal.
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Name
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Age
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| |
Position
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| Kamal Ghaffarian | | |
67
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| | Executive Chairman | |
| J. Clay Sell | | |
58
|
| | Chief Executive Officer and Director | |
| Daniel Gross | | | | | | Executive Vice President and Chief Financial Officer | |
| Edward Sonnenschein(2) | | |
71
|
| | Director | |
| Michael J. Wallace(3) | | |
78
|
| | Director | |
| Kathleen W. Hyle(1)(2) | | |
67
|
| | Director | |
| Christopher F. Ginther(3) | | |
64
|
| | Director | |
| Gregory J. Goff(1)(3) | | |
69
|
| | Director | |
| David B. Kaplan | | |
58
|
| | Director | |
| Allyson Satin(1)(2) | | |
40
|
| | Director | |
(1)
Member of the audit and risk committee
(2)
Member of the compensation and culture committee
(3)
Member of the nominating and corporate governance committee
The officers and members of the Board of Directors of the Company (the “Board”) are well qualified as leaders. In their prior positions, they have gained experience in core management skills, such as strategic and financial planning, financial reporting, compliance, risk management, and leadership development. Several of Company’s officers and directors also have experience serving on boards of directors and board committees of other public companies and private companies, and have an understanding of corporate governance practices and trends, which provides an understanding of different business processes, challenges, and strategies. Further, certain officers and directors have other experience that makes them valuable, such as prior experience in mergers and acquisitions, in financial services, managing and investing in assets.
We believe that the above-mentioned attributes, along with the leadership skills and other experiences of the officers and board members described below, will provide the Company with a diverse range of perspectives and judgment necessary to facilitate our goals and be good stewards of capital.
Executive Officers and Directors
Kamal Ghaffarian. Dr. Ghaffarian will serve as Executive Chairman of the Board. Throughout his more than 35-year career, Dr. Ghaffarian has created multiple successful companies and has gained extensive experience working at the intersection of government contracting and technological innovation.
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Dr. Ghaffarian started his entrepreneurial career in 1994 by founding Stinger Ghaffarian Technologies, Inc. (acquired by KBR, Inc. (NYSE: KBR)), a government services company focusing on IT, engineering, and science applications. Dr. Ghaffarian also held numerous technical and management positions at Lockheed Martin, Ford Aerospace and Loral. Dr. Ghaffarian holds a B.S. in Computer Science in Engineering from Catholic University of America, a B.S. in Electronics Engineering from Capital College, an M.S. in Science in Information Management from George Washington University, a Ph.D. in Management Information System from Kennedy Western University and a Ph.D. in Technology from Capital Technology University.
Dr. Ghaffarian is the co-founder and executive chairman of a number of companies including IBX, LLC, a venture capital firm, Axiom Space, Inc., a private space infrastructure company, Intuitive Machines, LLC, a space services and technologies company, and Quantum Space, LLC, a private spaceflight company. We believe Dr. Ghaffarian is qualified to serve on the Board because of his role as the executive chairman of X-energy, extensive experience in the field and deep understanding of company leadership.
J. Clay Sell. Mr. Sell will serve as Chief Executive Officer of the Company and as a member of Board. Mr. Sell has served as Chief Executive Officer of the Company since January 2019 and as a member of the Board since July 2021. From April 2008 to February 2018, Mr. Sell was the President of Hunt Energy Horizons, LLC, the renewable energy subsidiary of Hunt Consolidated, Inc., a multinational energy, real estate, and investment corporation controlled by the Ray L. Hunt family of Dallas. Previously, Mr. Sell held various positions for 14 years in the U.S. government, most recently as Deputy Secretary of Energy in the George W. Bush Administration (“Administration”) from March 2005 to February 2008. In that role, Mr. Sell served as Chief Operating Officer of the DOE and emerged as one of the leading advocates for the Administration’s nuclear energy policies. From 2003 to 2005, Mr. Sell served in the White House as a Special Assistant to the President for Economic Policy and a Special Assistant to the President for Legislative Affairs. From 1999 to 2003, he served as the Clerk for the Senate Energy & Water Subcommittee of Appropriations under the legendary Senator Pete Domenici of New Mexico. Mr. Sell began his career in Washington on the staff of future House Armed Services Committee Chairman Mac Thornberry of Texas from 1995 to 1999. Mr. Sell holds a J.D. from the University of Texas School of Law and a B.B.A. in Accounting from Texas Tech University. We believe Mr. Sell is qualified to serve on the Board because of his experience and leadership in the nuclear energy industry.
Daniel Gross. Mr. Gross will serve as Chief Financial Officer of the Company and as a member of the Board. Mr. Gross has served as Chief Financial Officer of the Company since December 2025 and was an Amazon designee on the Board from 2023 to December 2025. From to December 2025, Mr. Gross was a corporate development Director at Amazon. Prior to Amazon, he served as Chief Investment Officer at Climate Real Impact Solutions from to , Managing Director at Oaktree Capital Management from to , and Partner at Hudson Clean Energy from to . Mr. Gross holds masters degrees in business administration and environmental management, as well as a bachelors degree from Yale University, where he has also served as a renewable energy finance lecturer since 2016. We believe Mr. Gross is qualified to serve on the Board because of his extensive experience in energy finance, clean energy investment, and large-scale capital deployment.
Edward Sonnenschein. Mr. Sonnenschein will serve as a member of the Board. Mr. Sonnenschein has served on the Board since December 2021 and on the board of directors of Quantum Space, LLC, a private spaceflight company, since September 2022. He serves as Vice Chairman of IBX, LLC, where he provides leadership on governance and major transactions, as well as strategic guidance on financings, M&A, and new initiatives, and leads the legal function. Previously, Mr. Sonnenschein was an attorney at the leading global law firm Latham & Watkins, LLP from November 1979 to June 2021, where he was a widely respected deal maker and counselor for numerous public and private companies, private equity firms, sovereign wealth funds and family offices in hundreds of cutting-edge matters in M&A, private equity, venture capital, corporate governance, initial public offerings, other debt and equity offerings, securities regulation and leveraged finance. Mr. Sonnenschein also held numerous leadership positions at Latham, including as the firm’s Global Chair of the Corporate Department, Chair of the Strategic Initiatives Committee, Chair of the Business Development and Investment Committees and member of the Executive Committee. He was also a member of Coastview Capital LLC, a biotechnology venture capital firm, from July 2001 to October 2003. Mr. Sonnenschein holds an A.B. in Social Studies from Harvard College and a Juris Doctorate from Harvard Law School. We believe Mr. Sonnenschein is qualified to serve on the Board because of his experience and leadership in the legal, strategic transactions, financing and venture capital fields.
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Michael J. Wallace. Mr. Wallace will serve as a member of the Board. Mr. Wallace has served on the Board since December 2021. In addition, he is a member of the board of directors of Emirates Nuclear Energy Corporation, Nawah Energy Company, Barakah One Holding Company, and the U.S. Naval Historical Foundation. Since October 2017, Mr. Wallace has also served as a Senior Advisor at the North American Electric Reliability Council, where he advised stakeholders on matters related to assuring the reliability and security of the electricity grid. He was a member of the National Infrastructure Advisory Council from October 2017 to April 2022, where he advised the President of the U.S. on matters related to security of the country’s infrastructure. Mr. Wallace served as the senior-most nuclear industry executive at both Exelon (then known as ComEd) and Constellation Energy, where he also served as President and Vice Chairman of the Company. Mr. Wallace holds a B.S. in Electrical Engineering from Marquette University and an M.B.A. from the University of Chicago. We believe Mr. Wallace is qualified to serve on the Board because of his experience and leadership in the nuclear energy industry.
Kathleen W. Hyle. Ms. Hyle will serve as a member of the Board. Ms. Hyle was appointed to serve on the Board in January 2023. She served as Senior Vice President of Constellation Energy Corp (NASDAQ: CEG) and Chief Operating Officer of Constellation Energy Resources from November 2008 to March 2012. From June 2007 to November 2008, she served as Chief Financial Officer for Constellation Energy Nuclear Group and for UniStar Nuclear Energy, LLC. Prior to joining Constellation Energy in 2003, Ms. Hyle served as the Chief Financial Officer of ANC Rental Corporation, Vice President and Treasurer of AutoNation, Inc. (NYSE: AN), and Vice President and Treasurer of Stanley Black & Decker, Inc. (NYSE: SWK). Ms. Hyle has served on the board of AmerisourceBergen Corporation (NYSE: ABC) since May 2010 and on the board of Bunge Ltd (NYSE: BG) since July 2012. Ms. Hyle is a former member of the Board of Sponsors for the Loyola University Maryland Sellinger School of Business and Management and a former member of the Board of Trustees of CenterStage, a non-profit theatre in Baltimore, Maryland. Ms. Hyle holds a B.A. in Accounting from Loyola College. We believe Ms. Hyle is qualified to serve on the Board because of her experience and leadership in the energy industry.
Christopher F. Ginther. Mr. Ginther will serve as a member of the Board. Mr. Ginther has served on the Board since January 2023. He also served as Executive Vice President of OPG, a globally recognized leader in the development and production of clean energy and nuclear energy projects, from July 2012 until his retirement in May 2024, where he oversaw the company’s business strategy, development, commercial structuring, negotiations and commercial positioning in support of OPG’s growth strategy. Prior to OPG, he served as Vice President and General Counsel at Bell Canada Enterprises Inc. (NYSE: BCE) and as Senior Vice President, General Counsel and Corporate Secretary at Ontario Lottery and Gaming Corporation. Mr. Ginther began his legal career at the law firm Torys LLP in Toronto. Mr. Ginther holds a B.A. in History and Political Science from the University of Western Ontario and an L.L.B and L.L.M from Osgoode Hall Law School. He is also a Certified Public Accountant. We believe Mr. Ginther is qualified to serve on the Board because of his experience and leadership in the energy industry.
Gregory J. Goff. Mr. Goff will serve as a member of the Board. Mr. Goff has served on Board since July 2023. He currently serves on the board of directors of Avient Corporation (NYSE: AVNT) and was a member of the boards of directors of Enbridge Inc (NYSE: ENB) from February 2020 to June 2021 and Exxon Mobil Corporation (NYSE: XOM) from June 2021 to October 2024. Mr. Goff is the Chief Executive Officer of Claire Technologies, Inc., a technology company developing solutions to de-carbonize heavy modes of transportation using hydrogen, and the founder of GJG Energy, LLC, a company developing opportunities in the refining, marketing and logistics business. Mr. Goff was the Vice Chairman of Marathon Petroleum Corporation (NYSE: MPC), an integrated downstream energy company, from October 2018 to December 2019. He also served on the board of directors of MPLX L.P. (NYSE: MPLX) from October 2018 to December 2019. Prior to Marathon’s acquisition of Andeavor Corp. (“Andeavor”) (NYSE: ANDV), Mr. Goff served as Chairman, President and Chief Executive Officer of Andeavor, a leading petroleum refining and marketing company, from May 2010 to September 2018. He also served as Chairman and Chief Executive Officer of Andeavor Logistics, LP (NYSE: ANDX), an NYSE-listed master limited partnership that owned, operated and developed crude oil and refined products and logistics assets, from June 2011 to September 2018. Prior to that, Mr. Goff worked for ConocoPhillips Corporation, an integrated energy company, where he held a number of senior leadership positions, most recently Senior Vice President Commercial from 2008 to 2010. Mr. Goff holds a B.S. in Management and an M.B.A. from the University of Utah. We believe Mr. Goff is qualified to serve on the Board because of his experience and leadership in the energy industry.
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David B. Kaplan. Mr. Kaplan will serve as a member of the Board. Mr. Kaplan has served on the Board since December 2023. Mr. Kaplan is a Co-Founder, Director and Partner of Ares Management Corporation. Mr. Kaplan serves on several Ares Investment Committees including, among others, the Ares Private Equity Group’s Corporate Opportunities, Energy Opportunities and Extended Value Investment Committees and the Ares Credit Group’s Opportunistic Credit Investment Committee. Additionally, Mr. Kaplan served as Chief Executive Officer and Co-Chairman of the board of directors of Ares Acquisition Corporation II from March 2021 to September 2025. Mr. Kaplan joined Ares in 2003 from Shelter Capital Partners, LLC, where he was a Senior Principal from June 2000 to April 2003. From 1991 through 2000, Mr. Kaplan was a Senior Partner of Apollo Management, L.P. (“Apollo”) and its affiliates. Prior to Apollo, Mr. Kaplan was a member of the Investment Banking Department at Donaldson, Lufkin & Jenrette Securities Corp. Mr. Kaplan currently serves on the supervisory board of directors of LuxExperience B.V., formerly known as MYT Netherlands Parent B.V. Mr. Kaplan also serves as the Chairman of the board of directors of the parent entity of Cooper’s Hawk Winery & Restaurants. Mr. Kaplan’s previous public company board experience includes Floor & Decor Holdings, Inc., Maidenform Brands, Inc., where he served as the company’s Chairman, GNC Holdings, Inc., Dominick’s Supermarkets, Inc., Stream Global Services, Inc., Orchard Supply Hardware Stores Corporation, Smart & Final Stores, Inc. and Allied Waste Industries Inc. Mr. Kaplan also currently serves as the Chairman of the Board of Directors of Cedars-Sinai Medical Center, and is on the Board of Trustees at the Los Angeles County Museum of Art (LACMA). Mr. Kaplan sits on the President’s Advisory Group of the University of Michigan, where he graduated with High Distinction, Beta Gamma Sigma, with a Bachelor of Business Administration degree, concentrating in Finance. We believe Mr. Kaplan is well qualified to serve on the Board due to his knowledge of and extensive experience with leveraged finance, acquisitions and private equity investments, in addition to his service as a director of other public and private companies.
Allyson Satin. Ms. Satin will serve as a member of the Board. Ms. Satin previously served on the Board from December 2023 to July 2025. Ms. Satin is a Partner in the Ares Corporate Strategy Group of Ares Management Corporation, where she focuses on the firm’s SPAC Business. Ms. Satin previously served as the Chief Operating Officer of Ares Acquisition Corporation II from March 2021 through September 2025, and has served as a member of the board of directors of its successor, Kodiak AI, Inc. (NASDAQ: KDK) since September 2025. From 2009 to 2020, Ms. Satin was an investment professional in the Ares Private Equity Group where she participated in various leveraged buyouts, growth equity and distressed debt transactions. Prior to joining Ares in 2009, Ms. Satin was an investment banking analyst in the Global Financial Sponsors Group at Barclays Capital (formerly Lehman Brothers). Ms. Satin holds a B.S. from the University of California, Berkeley Haas School of Business in Business Administration. We believe Ms. Satin is well qualified to serve on the Board due to her knowledge of and extensive experience with leveraged finance, acquisitions and private equity investments, in addition to her service as a director of other companies.
Corporate Governance
Composition of the Board
Our business and affairs will be managed under the direction of the Board. The Board will be chaired by Kamal Ghaffarian and will include J. Clay Sell, Edward Sonnenschein, Michael J. Wallace, Kathleen W. Hyle, Christopher F. Ginther, Gregory J. Goff, David B. Kaplan and Allyson Satin as members. The Board is expected to determine whether , , , , and qualify as independent in accordance with applicable Nasdaq rules. Subject to the terms of the Amended and Restated Certificate of Incorporation and Amended and Restated Bylaws, the number of directors will be fixed by the Board.
When considering whether directors and director nominees have the experience, qualifications, attributes and skills, taken as a whole, to enable the Board to satisfy its oversight responsibilities effectively in light of its business and structure, the Board expects to focus primarily on each person’s background and experience as reflected in the information discussed in each of the directors’ individual biographies set forth above in order to provide an appropriate mix of experience and skills relevant to the size and nature of its business.
Director Independence
Nasdaq listing standards require that a majority of the board of directors be independent. An “independent director” is defined generally as a person other than an officer or employee of the company or
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its subsidiaries or any other individual having a relationship which in the opinion of the board of directors, would interfere with the director’s exercise of independent judgment in carrying out the responsibilities of a director.
The Board will undertake a review of its composition, the composition of its committees and the independence of its directors and consider whether any director has a material relationship with the Company that could compromise his or her ability to exercise independent judgment in carrying out his or her responsibilities.
We anticipate that the Company will have “independent directors” as defined in Nasdaq listing standards and applicable SEC rules.
Classified Board of Directors
Pursuant to the Certificate of Incorporation, the Company’s directors will be divided into three classes, with each class serving staggered three-year terms. The Board will initially consist of members. The Board will be divided among the three classes as follows:
•
The Class I directors are , and ;
•
The Class II directors are , and ; and
•
The Class III directors are , and .
Committees of the Board
The Board will direct the management of its business and affairs, as provided by Delaware law, and conduct its business through meetings of the Board and standing committees. The Board will have a standing audit and risk committee, compensation and culture committee and nominating and corporate governance committee, each of which will operate under a written charter that will be posted on the Investors Relations page of the Company’s website at https://x-energy.com/investors as required by applicable Nasdaq rules.
From time to time, special committees may be established under the direction of the Board when the Board deems it necessary or advisable to address specific issues.
Audit and Risk Committee
The Board’s audit and risk committee will be responsible for, among other things:
•
appointing, compensating, retaining and overseeing the work of our independent registered public accounting firm and any other registered public accounting firm engaged for the purpose of preparing or issuing an audit report or related work or performing other audit, review or attest services for us;
•
assessing the independence of our independent registered public accounting firm;
•
pre-approving all audit and non-audit services provided to us by our independent registered public accounting firm (other than those provided pursuant to appropriate preapproval policies established by the audit committee or exempt from such requirement under the rules of the SEC);
•
discussing with our independent registered public accounting firm any audit problems or difficulties and management’s response;
•
reviewing and discussing our annual and quarterly financial statements with management and our independent registered public accounting firm;
•
reviewing, discussing and evaluating our policies with respect to risk assessment and risk management;
•
reviewing and approving or ratifying any related person transactions;
•
reviewing and discussing our internal control over financial reporting and code of business conduct and ethics;
•
setting clear hiring policies for employees or former employees of our independent registered public accounting firm;
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•
establishing procedures for the receipt, retention and treatment of complaints received by us regarding accounting, internal accounting controls or auditing matters, and for the confidential and anonymous submission by our employees of concerns regarding questionable accounting or auditing matters; and
•
preparing the audit committee report for inclusion in our annual proxy statements.
Our audit and risk committee is expected to consist of Kathleen W. Hyle, Gregory J. Goff and Allyson Satin with Kathleen W. Hyle serving as chair. All members of our audit and risk committee will meet the requirements for financial literacy under the applicable Nasdaq rules and regulations. The Board expects to affirmatively determine that each member of the audit and risk committee qualifies as “independent” under the Nasdaq’s additional standards applicable to audit committee members and Rule 10A-3 of the Exchange Act applicable to audit committee members. The Board expects to determine that Kathleen W. Hyle qualifies as an “audit committee financial expert,” as such term is defined in Item 407(d)(5) of Regulation S-K.
Compensation and Culture Committee
The Board’s compensation and culture committee will be responsible for, among other things:
•
reviewing and approving corporate goals and objectives with respect to the compensation of our Chief Executive Officer, evaluating our Chief Executive Officer’s performance in light of these goals and objectives and setting our Chief Executive Officer’s compensation;
•
reviewing and setting or making recommendations to the Board regarding the compensation of our other executive officers;
•
reviewing and making recommendations to the Board regarding director compensation;
•
reviewing and approving or making recommendations to the Board regarding our incentive compensation and equity-based plans, policies and programs and administering the plans;
•
reviewing and discussing annually with management our “Compensation Discussion and Analysis,” to the extent it is required to be included in our annual report on Form 10-K or annual proxy statement;
•
overseeing and reviewing with management our strategies, policies and practices regarding human capital management and talent development; and
•
preparing the annual compensation committee report required by SEC rules, to the extent required.
Our compensation and culture committee is expected to consist of Edward Sonnenschein, Kathleen W. Hyle and Allyson Satin, with Edward Sonnenschein serving as chair. The Board expects to determine that and qualify as “independent” under the Nasdaq’s additional standards applicable to compensation committee members.
Nominating and Corporate Governance Committee
The Board’s nominating and corporate governance committee will be responsible for, among other things:
•
identifying individuals qualified to become members of the Board and ensuring that the Board has the requisite expertise and consists of persons with sufficiently diverse and independent backgrounds;
•
recommending to the Board the persons to be nominated for election as directors and to each committee of the Board;
•
developing and recommending to the Board corporate governance guidelines, and reviewing, reassessing the adequacy of such corporate governance guidelines and recommending any proposed changes to the Board for approval from time to time; and
•
overseeing the annual self-evaluations of the Board and its committees.
Our nominating and corporate governance committee is expected to consist of Gregory J. Goff, Christopher F. Ginther and Michael J. Wallace, with Gregory J. Goff serving as chair. The Board expects to determine that Gregory J. Goff and Michael J. Wallace qualify as “independent” under Nasdaq rules applicable to nominating and corporate governance committee members.
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Code of Ethics
The Company will adopt a Code of Business Conduct and Ethics that applies to all of our executive officers, directors and employees, including our principal executive officer, principal financial officer or principal accounting officer or persons performing similar functions, which will be available on our website. Our Code of Business Conduct and Ethics will be a “code of ethics,” as defined in Item 406(b) of Regulation S-K.
We intend to make any legally required disclosures regarding amendments to, or waivers of, provisions of our code of ethics on our website.
Compensation Committee Interlocks and Insider Participation
No anticipated member of the Board’s compensation committee was at any time during fiscal year 2024, or at any other time, one of our officers or employees. None of our executive officers has served as a director or member of a compensation committee (or other committee serving an equivalent function) of any entity, one of whose executive officers is anticipated to serve as a member of the Board or of its compensation committee.
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EXECUTIVE AND DIRECTOR COMPENSATION
This section discusses the material components of the executive compensation program for our executive officers who are named in the “2025 Summary Compensation Table” below. With respect to the year ended December 31, 2025, our “named executive officers” or “NEOs” were as follows:
•
J. Clay Sell, Chief Executive Officer;
•
Daniel Gross, Executive Vice President and Chief Financial Officer; and
•
Dragan Popovic, Executive Vice President and Global Chief Operating Officer.
This discussion may contain forward-looking statements that are based on our current plans, considerations, expectations and determinations regarding future compensation programs. Actual compensation programs that we adopt may differ materially from the currently planned programs summarized in this discussion.
2025 Summary Compensation Table
The following table sets forth information concerning the compensation of our named executive officers for the year ended December 31, 2025.
|
Name and Principal Position
|
| |
Salary
($)(1) |
| |
Bonus
($) |
| |
Stock
Awards ($)(2) |
| |
Non-Equity
Incentive Plan Compensation ($) |
| |
All Other
Compensation ($)(3) |
| |
Total
($) |
| ||||||||||||||||||
|
J. Clay Sell
Chief Executive Officer |
| | | | 612,000 | | | | | | | | | | | | 9,681,696 | | | | | | 612,000 | | | | | | 113,692 | | | | | | 11,019,388 | | |
|
Daniel Gross(4)
Executive Vice President and Chief Financial Officer |
| | | | 36,264 | | | | | | | | | | | | 7,221,892 | | | | | | | | | | | | 1,058 | | | | | | 7,259,214 | | |
|
Dragan Popovic(5)(6)
Executive Vice President and Global Chief Operating Officer |
| | | | 88,618 | | | | | | 134,375 | | | | | | 5,055,322 | | | | | | | | | | | | | | | | | | 5,278,315 | | |
(1)
Amounts reflect base salary earned during 2025.
(2)
Amounts reflect the aggregate grant date fair value of profits interests in Management LLC granted during the year ended December 31, 2025 computed in accordance with FASB ASC Topic 718, Compensation — Stock Compensation and does not correspond to the actual economic value that may be received by the named executive officers from these awards. We provide information regarding the assumptions used to calculate the value of all profits interests made to named executive officers in Note 12 — Unit-Based Compensation Expense to the financial statements included in this prospectus.
(3)
Amounts reflect (i) $19,701 and $1,058 in employer matching contributions made to the X-energy defined contribution plan, for Messrs. Sell and Gross, respectively; and (ii) $93,991 in reimbursements to Mr. Sell for expenses incurred in connection with travel to and from his primary residence.
(4)
Mr. Gross commenced employment as our Executive Vice President and Chief Financial Officer in November 2025.
(5)
Mr. Popovic commenced employment as our Executive Vice President and Global Chief Operating Officer in October 2025.
(6)
During his period of employment prior to December 22, 2025, Mr. Popovic was employed by our subsidiary, X-Energy Canada, Inc., and was paid in local currency (CAD). The amounts for Mr. Popovic earned in local currency have been converted to USD using an exchange rate for December 31, 2025 of 1 USD to 1.37 CAD.
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Narrative to Summary Compensation Table
2025 Salaries
Each of our named executive officers receives an annual base salary to compensate the executive for services rendered to us. The base salary payable to each named executive officer is intended to provide a fixed component of compensation reflecting the executive’s duties and authorities, contributions, prior experience and sustained performance.
The 2025 annual base salaries for our named executive officers were $612,000 for Mr. Sell, $550,000 for Mr. Gross, and $450,000 for Mr. Popovic.
The “Salary” column of the 2025 Summary Compensation Table above shows the actual base salaries earned by each named executive officer in 2025.
Cash Incentive Compensation
Annual cash bonuses are determined by our Compensation and Culture Committee and set at a level that is commensurate with the executive’s duties and authorities, contributions, prior experiences and sustained performance. The discretionary cash bonus earned by Mr. Sell for fiscal year 2025 was $612,000. Mr. Gross was not eligible for an annual bonus for fiscal year 2025, and Mr. Popovic received a guaranteed annual cash bonus of $134,375 for fiscal year 2025, as described in the section entitled “Executive Compensation Arrangements” below.
Equity Compensation
2025 Equity Awards
Prior to the closing, Management LLC typically granted Class B-2 Common Units under the Management LLC Profits Interest Plan (the “Profits Interest Plan”). We refer to these Management LLC Class B-2 Common Units as “Incentive Units.” We granted equity awards in the form of Class B Common Units of Management LLC intended to qualify as profits interests within the meaning of applicable tax guidance. The grant of Class B Units is implemented through an “upstairs-downstairs” structure, such that our employees, including our named executive officers, receive Class B Units of Management LLC that mirror the economics (including vesting schedules) of corresponding units that X-energy issues to Management LLC.
In June 2025, we granted 2,576,000 Incentive Units to Mr. Sell and, in December 2025, we granted the following Incentive Units to our named executive officers: 1,147,800 Incentive Units to Mr. Sell, 2,051,674 Incentive Units to Mr. Gross and 1,436,171 Incentive Units to Mr. Popovic.
The Incentive Unit awards each vest , subject to the named executive officer’s continuous employment through the applicable vesting date. The vesting commencement date for the Incentive Unit awards granted to Mr. Sell in June 2025 is January 1, 2024, and the vesting commencement date for the Incentive Unit awards granted to Messrs. Sell, Gross and Popovic in December 2025 is December 23, 2025.
In connection with this initial public offering, both the Company and Management LLC will effectuate a recapitalization, pursuant to which all outstanding units in each entity will be recapitalized into common units in accordance with the applicable operating agreement (on a “value-for-value” basis based on the fair market value of the equity interests, including the Incentive Units, at the time of the offering and the common stock price in the offering). Following the consummation of this offering, the resulting common units will continue to be subject to any applicable vesting conditions of such units before the applicable recapitalization. In addition, in connection with this offering we expect the Profits Interests Plan will terminate and we will not make further awards under the Profits Interest Plan.
2026 Incentive Award Plan
In connection with this offering, we intend to adopt the 2026 Incentive Award Plan, or the 2026 Plan, in order to facilitate the grant of cash and equity incentives to affiliates’ directors, employees (including our named executive officers) and consultants of our company and certain of our affiliates and to enable our
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company and certain of our affiliates to obtain and retain services of these individuals, which is essential to our long-term success. For additional information about the 2026 Plan, please see the section titled “2026 Incentive Award Plan” below.
Other Elements of Compensation and Compensation Policies
We provide benefits to our named executive officers on the same basis as provided to all of our employees, including health, dental and vision insurance; critical illness insurance; life insurance; accident insurance; hospital indemnity insurance; short-and long-term disability insurance; and a tax-qualified Section 401(k) plan for which we make safe harbor contributions on behalf of our employees. In 2025, we also provided Mr. Sell with compensation to cover expenses incurred by him in connection with travel to and from his primary residence (including commuting, lodging and dining expenses).
In addition to the health and welfare benefits described above, prior to his relocation to the United States in December 2025, Mr. Popovic was eligible to receive similar health and welfare benefits in connection with his employment in Canada.
We believe the employee benefits and perquisites described above are necessary and appropriate to provide a competitive compensation package to our named executive officers.
No Tax Gross-Ups
We do not make gross-up payments to cover our named executive officers’ personal income taxes that may pertain to any of the compensation or perquisites we pay or provide.
Clawback Policy
In connection with this offering, our Board intends to adopt a compensation recovery policy that complies with the listing standards of Nasdaq, as required by the Dodd-Frank Act.
Outstanding Equity Awards at Fiscal Year-End
The following table summarizes the number of outstanding unvested Incentive Units held by each named executive officer as of December 31, 2025.
|
Name
|
| |
Grant Date
|
| |
Number of Incentive
Units That Have Not Vested (#) |
| |
Market Value of
Incentive Units That Have Not Vested ($)(1) |
| |||
|
J. Clay Sell
|
| | June 13, 2025 | | | | | 1,932,000(2) | | | | | |
| | | |
December 23, 2025
|
| | | | 1,147,800(3) | | | | | |
|
Daniel Gross
|
| |
December 23, 2025
|
| | | | 2,051,674(3) | | | | | |
|
Dragan Popovic
|
| |
December 23, 2025
|
| | | | 1,436,171(3) | | | | | |
(1)
The Incentive Units are not publicly traded and, therefore, there was no ascertainable public market value for the Incentive Units as of December 31, 2025. The value of the Incentive Units is estimated as of December 31, 2025 based on the number of outstanding unvested Incentive Units as of such date and taking into account applicable distribution thresholds, but excluding the value of catch-up distributions that could be payable to certain Incentive Units (for a description of the catch-up distribution payments, refer to Note 12 to X-energy’s unaudited consolidated financial statements included elsewhere in this prospectus), and was estimated to be $ . If the distribution thresholds were not taken into account, then the per unit value of the unvested Incentive Units would have been approximately $ .
(2)
Represents unvested Incentive Units that will vest in substantially equal annual installments on each of the first, second, third and fourth anniversaries of January 1, 2024, subject to Mr. Sell’s continuous service through the applicable vesting date. The distribution threshold is $1,729,728,630.
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(3)
Represents unvested Incentive Units that will vest in substantially equal annual installments on each of the first, second, third and fourth anniversaries of the grant date, subject to the named executive officer’s continuous service through the applicable vesting date. The distribution threshold is $5,000,000,000.
Executive Compensation Arrangements
Each of Messrs. Sell, Gross and Popovic is party to an offer letter with X Energy, LLC that provides for at-will employment that will continue until terminated at any time by either party. Pursuant to the terms of his offer letter, Mr. Gross is eligible for an annual cash incentive bonus (targeted at 75% of his base salary) commencing in the 2026 performance year, and is entitled to receive a monthly stipend covering reasonable expenses related to executive housing, travel and other expenses associated with commuting to the company’s Maryland headquarters, and reimbursement of up to $175,000 in relocation expense reimbursements. Pursuant to the terms of his offer letter, Mr. Popovic is eligible for an annual cash incentive bonus (targeted at 75% of his base salary), with a guaranteed bonus of $134,375 for 2025, and is entitled to receive reimbursement of travel expenses for commuting, lodging, and house-hunting trips, and up to an additional $135,000 in relocation expense reimbursements. As of the end of 2025, Mr. Gross had not received any commuting expense reimbursements, and neither Mr. Gross nor Mr. Popovic had received any relocation expense reimbursements. Pursuant to their offer letters, each of our named executive officers is eligible to participate in the benefit plan and programs maintained by us for the benefit of our employees. None of the offer letters provide for severance payments on termination of employment.
Each of Messrs. Sell, Gross and Popovic also entered into the Company’s standard form of non-disclosure and non-solicitation agreement, which includes a company information non-disclosure covenant that lasts during employment and for five years thereafter, a perpetual government data non-disclosure covenant, and an employee and client non-solicitation covenant that lasts during employment and for two years thereafter. In addition, as a condition to their receipt of Incentive Units, they each entered into a restrictive covenant letter, which includes non-competition and employee and business relationship non-solicitation covenants that apply during employment and for one year following termination of employment, a company information non-disclosure covenant and non-disparagement covenant that each apply during the period they provide services to X-energy and thereafter, and an assignment of intellectual property covenant.
2026 Incentive Award Plan
In connection with this offering, we intend to adopt the 2026 Plan, under which we may grant equity and cash incentive awards in order to attract, motivate and retain the talent for which we compete, subject to stockholder approval. The material terms of the 2026 Plan are summarized below.
Eligibility and Administration. Our employees, consultants and directors of our affiliates will be eligible to receive awards under the 2026 Plan. Following the completion of this offering, the 2026 Plan will be administered by our board of directors with respect to awards to non-employee directors and by our compensation committee with respect to other participants, each of which may delegate its duties and responsibilities to committees of our directors and/or officers (referred to collectively as the plan administrator), subject to the limitations imposed under the 2026 Plan, Section 16 of the Exchange Act, stock exchange rules and other applicable laws. The plan administrator will have the authority to take all actions and make all determinations under the 2026 Plan, to interpret the 2026 Plan and award agreements and to adopt, amend and repeal rules for the administration of the 2026 Plan as it deems advisable. The plan administrator will also have the authority to determine which eligible service providers receive awards, grant awards and set the terms and conditions of all awards under the 2026 Plan, including any vesting and vesting acceleration provisions, subject to the conditions and limitations in the 2026 Plan.
Limitation on Awards and Shares Available. The initial aggregate number of shares of our common stock that will be available for issuance under the 2026 Plan will be equal to % of the number of shares of our Class A common stock outstanding as of immediately following the completion of this offering (which is expected to be shares, assuming an initial public offering price of $ per share, which is the midpoint of the estimated price range set forth on the cover page of this prospectus). In addition, the number of shares of our common stock available for issuance under the 2026 Plan will be subject to an annual increase on the first day of each calendar year beginning on and including January 1, 2027 and ending on and including January 1, 2036, equal to the lesser of (A) % of the aggregate number of shares of our Class A common
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stock outstanding on the final day of the immediately preceding calendar year and (B) such smaller number of shares as is determined by our board of directors. The maximum number of shares that may be issued pursuant to the exercise of incentive stock options, or ISOs, granted under the 2026 Plan, will be . Any shares issued pursuant to the 2026 Plan may consist, in whole or in part, of authorized and unissued common stock, treasury common stock or common stock purchased on the open market.
If an award under the 2026 Plan expires, lapses or is terminated, exchanged for or settled in cash, any shares subject to such award (or portion thereof) may, to the extent of such expiration, lapse, termination or cash settlement, be used again for new grants under the 2026 Plan. Shares tendered or withheld to satisfy the exercise price or tax withholding obligation for any award will not reduce the shares available for grant under the 2026 Plan. Further, the payment of dividend equivalents in cash in conjunction with any awards under the 2026 Plan will not reduce the shares available for grant under the 2026 Plan. However, the following shares may not be used again for grant under the 2026 Plan: (i) shares subject to stock appreciation rights, or SARs, that are not issued in connection with the stock settlement of the SAR on exercise, and (ii) shares purchased on the open market with the cash proceeds from the exercise of options.
Awards granted under the 2026 Plan upon the assumption of, or in substitution for, awards authorized or outstanding under a qualifying equity plan maintained by an entity with which we enter into a merger or similar corporate transaction will not reduce the shares available for grant under the 2026 Plan but will count against the maximum number of shares that may be issued upon the exercise of ISOs.
The 2026 Plan provides that, commencing with calendar year 2027, the sum of any cash compensation and the aggregate grant date fair value (determined as of the date of the grant under Financial Accounting Standards Board Accounting Standards Codification Topic 718, or any successor thereto) of all awards granted to a non-employee director as compensation for services as a non-employee director during any fiscal year, or director limit, may not exceed an amount equal to $ (increased to $ in the calendar year of a non-employee director’s initial service as a non-employee director or any calendar year during which a non-employee director serves as chair of our Board or lead independent director), which limits shall not apply to the compensation for any non-employee director who serves in any capacity in addition to that of a non-employee director for which he or she receives additional compensation or any compensation paid prior to the calendar year following the calendar year in which the 2026 Plan becomes effective.
Awards. The 2026 Plan provides for the grant of stock options, including ISOs and nonqualified stock options, or NSOs, SARs, restricted stock, dividend equivalents, restricted stock units, or RSUs, and other stock or cash-based awards. Certain awards under the 2026 Plan may constitute or provide for payment of “nonqualified deferred compensation” under Section 409A of the Code, which may impose additional requirements on the terms and conditions of such awards. All awards under the 2026 Plan will be evidenced by award agreements, which will detail the terms and conditions of the awards, including any applicable vesting and payment terms and post-termination exercise limitations. Awards other than cash awards generally will be settled in shares of our common stock, but the applicable award agreement may provide for cash settlement of any award. A brief description of each award type follows.
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Stock Options and SARs. Stock options provide for the purchase of shares of our common stock in the future at an exercise price set on the grant date. ISOs, in contrast to NSOs, may provide tax deferral beyond exercise and favorable capital gains tax treatment to their holders if certain holding period and other requirements of the Code are satisfied. SARs entitle their holder, upon exercise, to receive from us an amount equal to the appreciation of the shares subject to the award between the grant date and the exercise date. Unless otherwise determined by our board, the exercise price of a stock option or SAR may not be less than 100% of the fair market value of the underlying share on the grant date (or 110% in the case of ISOs granted to certain significant stockholders), except with respect to certain substitute awards granted in connection with a corporate transaction. The term of a stock option or SAR may not be longer than ten years (or five years in the case of ISOs granted to certain significant stockholders). Conditions applicable to stock options and/or SARs may be based on continuing service, the attainment of performance goals and/or such other conditions as the plan administrator may determine.
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Restricted Stock and RSUs. Restricted stock is an award of nontransferable shares of our common stock that are subject to certain vesting conditions and other restrictions. RSUs are contractual
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promises to deliver shares of our common stock in the future, which may also remain forfeitable unless and until specified conditions are met and may be accompanied by the right to receive the equivalent value of dividends paid on shares of our common stock prior to the delivery of the underlying shares (i.e., dividend equivalent rights). The plan administrator may provide that the delivery of the shares underlying RSUs will be deferred on a mandatory basis or at the election of the participant. The terms and conditions applicable to RSUs will be determined by the plan administrator, subject to the conditions and limitations contained in the 2026 Plan. Conditions applicable to restricted stock and RSUs may be based on continuing service, the attainment of performance goals and/or such other conditions as the plan administrator may determine.
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Other Stock or Cash-Based Awards. Other stock or cash-based awards are awards of cash, fully vested shares of our common stock and other awards valued wholly or partially by referring to, or otherwise based on, shares of our common stock. Other stock or cash-based awards may be granted to participants and may also be available as a payment form in the settlement of other awards, as standalone payments and as payment in lieu of compensation to which a participant is otherwise entitled.
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Dividend Equivalents. Dividend equivalents represent the right to receive the equivalent value of dividends paid on shares of our common stock and may be granted alone or in tandem with awards other than stock options or SARs. Dividend equivalents are credited as of the dividend record dates during the period between the date an award is granted and the date such award vests, is exercised, is distributed or expires, as determined by the plan administrator. Dividend equivalents payable with respect to an award prior to the vesting of such award instead will be paid out to the participant only to the extent that the vesting conditions are subsequently satisfied and the award vests.
Certain Transactions. The plan administrator has broad discretion to take action under the 2026 Plan, as well as make adjustments to the terms and conditions of existing and future awards, to prevent the dilution or enlargement of intended benefits and facilitate necessary or desirable changes in the event of certain transactions and events affecting our common stock, such as stock dividends, stock splits, mergers, acquisitions, consolidations and other corporate transactions. In addition, in the event of certain non-reciprocal transactions with our stockholders known as “equity restructurings,” the plan administrator will make equitable adjustments to the 2026 Plan and outstanding awards. In the event of a change in control (as defined in the 2026 Plan), to the extent that the surviving entity declines to continue, convert, assume or replace outstanding awards, then all such awards will become fully vested and exercisable in connection with the transaction. Upon or in anticipation of a change in control, the plan administrator may cause any outstanding awards to terminate at a specified time in the future and give the participant the right to exercise such awards during a period of time determined by the plan administrator in its sole discretion. Individual award agreements may provide for additional accelerated vesting and payment provisions.
Repricing. Our board of directors may, without approval of the stockholders, reduce the exercise price of any stock option or SAR, or cancel any stock option or SAR in exchange for cash, other awards or stock options or SARs with an exercise price per share that is less than the exercise price per share of the original stock options or SARs.
Plan Amendment and Termination. Our board of directors may amend or terminate the 2026 Plan at any time; however, no amendment, other than an amendment that increases the number of shares available under the 2026 Plan, may materially and adversely affect an award outstanding under the 2026 Plan without the consent of the affected participant, and stockholder approval will be obtained for any amendment to the extent necessary to comply with applicable laws. The 2026 Plan will remain in effect until the tenth anniversary of the effective date of the 2026 Plan, unless earlier terminated. No awards may be granted under the 2026 Plan after its termination.
Foreign Participants, Claw-back Provisions, Transferability and Participant Payments. The plan administrator may modify award terms, establish subplans and/or adjust other terms and conditions of awards, subject to the share limits described above, in order to facilitate grants of awards subject to the laws and/or stock exchange rules of countries outside of the U.S. All awards will be subject to any Company clawback policy as set forth in such clawback policy or the applicable award agreement. Awards under the 2026 Plan are generally non-transferrable, except by will or the laws of descent and distribution, or, subject to the plan
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administrator’s consent, pursuant to a domestic relations order, and are generally exercisable only by the participant. With regard to tax withholding, exercise price and purchase price obligations arising in connection with awards under the 2026 Plan, the plan administrator may, in its discretion, accept cash or check, shares of our common stock that meet specified conditions, a “market sell order” or such other consideration as it deems suitable.
Director Compensation
During the fiscal year ended December 31, 2025, our non-employee directors who received compensation were Dr. Kam Ghaffarian, Christopher F. Ginther, Gregory J. Goff, Kathleen W. Hyle and Michael J. Wallace, who we refer to as our non-employee directors in this section.
2025 Director Compensation Table
The following table sets forth information for 2025 regarding the compensation awarded to, earned by or paid to the non-employee directors.
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Name
|
| |
Fees Earned or
Paid in Cash ($)(1) |
| |
Stock Awards
($)(1) |
| |
Total
($) |
| |||||||||
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Dr. Kam Ghaffarian
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| | | | 400,000 | | | | | | | | | | | | 400,000 | | |
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Christopher F. Ginther(2)
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| | | | 58,549 | | | | | | 519,440 | | | | | | 577,989 | | |
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Gregory J. Goff
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| | | | 95,000 | | | | | | 519,440 | | | | | | 614,440 | | |
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Kathleen W. Hyle
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| | | | 100,000 | | | | | | 519,440 | | | | | | 619,440 | | |
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Michael J. Wallace
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| | | | 80,000 | | | | | | 295,840 | | | | | | 375,840 | | |
(1)
Amounts reflect the aggregate grant date fair value of profits interests granted during the year ended December 31, 2025 computed in accordance with FASB ASC Topic 718, Compensation — Stock Compensation and does not correspond to the actual economic value that may be received by the non-employee directors from these awards. We provide information regarding the assumptions used to calculate the value of all profits interests made to non-employee directors in Note 12 — Unit-Based Compensation Expense to the financial statements included in this prospectus.
(2)
The amounts for Mr. Ginther originally denoted in local currency (CAD) have been converted to USD using an average exchange rate for December 31, 2025 of 1 USD to 1.37 CAD.
The following table summarizes the number of outstanding unvested Incentive Units held by each non-employee director, as of December 31, 2025.
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Name
|
| |
Stock Awards
|
| |
Total
($) |
| |||
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Dr. Kam Ghaffarian
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| | | | — | | | | | |
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Christopher F. Ginther
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| | | | 129,500 | | | | | |
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Gregory J. Goff
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| | | | 129,500 | | | | | |
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Kathleen W. Hyle
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| | | | 80,750 | | | | | |
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Michael J. Wallace
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| | | | 83,250 | | | | | |
Non-Employee Director Compensation Program
In connection with this offering, we intend to approve and implement a compensation program for our non-employee directors. We anticipate that the non-employee director compensation program will provide for annual cash retainer fees and long-term equity awards.
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CERTAIN RELATIONSHIPS AND RELATED PARTY TRANSACTIONS
The following includes a summary of transactions since January 1, 2023 and any currently proposed transactions, to which we were or are to be a participant, in which (i) the amount involved exceeded or will exceed $120,000; and (ii) any of our directors, executive officers, or holders of more than 5% of our capital stock, or any affiliate or member of the immediate family of the foregoing persons or entities, had or will have a direct or indirect material interest, other than compensation and other arrangements that are described under “Executive and Director Compensation.”
We believe the terms obtained or consideration that we paid or received, as applicable, in connection with the transactions described below were comparable to terms available or the amounts that we would pay or receive, as applicable, in arm’s-length transactions.
Transactions
In connection with the Transactions, we will engage in certain transactions with certain of our directors, executive officers and other persons and entities which are or will become holders of 5% or more of our voting securities upon the consummation of the Transactions. These transactions are described in “Organizational Structure.”
XERC LLC Agreement
In connection with the closing of this offering, XERC will amend and restate its limited liability company agreement by adopting the XERC LLC Agreement. The XERC LLC Agreement will (i) permit the issuance and ownership of the post-offering equity of XERC and (ii) admit X-energy as the managing member of XERC.
Appointment as Managing Member. Under the XERC LLC Agreement, X-Energy, Inc. is a member and the managing member of XERC. As the managing member, X-Energy, Inc. is able to control all of the day-to-day business affairs and decision-making of XERC without the approval of any other member, unless otherwise stated in the XERC LLC Agreement. As such, X-Energy, Inc., through its officers and directors, will be responsible for all operational and administrative decisions of XERC and the day-to-day management of XERC’s business, unless otherwise stated in the XERC LLC Agreement. Pursuant to the terms of the XERC LLC Agreement, X-Energy, Inc. cannot be removed as the managing member of XERC by other members.
Compensation. X-Energy, Inc. is not entitled to compensation for its services as managing member. X-Energy, Inc. is entitled to reimbursement by XERC for fees and expenses incurred on behalf of XERC, including all expenses associated with the Transactions and maintaining its corporate existence.
Capitalization. The XERC LLC Agreement provides for a single class of Common Units. All Common Units shall have identical rights and privileges in all respects. Each Common Unit entitles the holder to a pro rata share of the net profits and net losses and distributions of XERC.
Distributions. The XERC LLC Agreement requires “Tax Distributions,” as that term is defined in the XERC LLC Agreement, to be made by XERC to X-Energy, Inc. and to its “Members,” as that term is defined in the XERC LLC Agreement. Tax Distributions shall be made quarterly to X-Energy, Inc. and each Member based on the greater of (i) their allocable share of the taxable income of XERC multiplied by a tax rate that will be determined by X-Energy, Inc. and (ii) the pro rata amount of tax distributions paid to other Members holding the same class of equity. The tax rate used to determine tax distributions will apply regardless of the actual final tax liability of any such member. The XERC LLC Agreement also allows for distributions to be made by XERC to its members on a pro rata basis out of “distributable cash,” which is the amount of cash that may be distributed by XERC to its Members in accordance with existing credit agreements.
LLC Unit Redemption Right. The XERC LLC Agreement provides a redemption right to the Members (other than X-Energy, Inc. and its subsidiaries) and option holders (in connection with the exercise of an XERC Option, as such term is defined in the XERC LLC Agreement), which entitles them to have their units redeemed, in whole or in part, at the election of each such person, for newly-issued shares of X-Energy, Inc. Class A common stock on a one-to-one basis or, to the extent there is cash available from a contemporaneous
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public offering or private sale of X-Energy, Inc. Class A common stock by X-Energy, Inc., cash (in each case, subject to the terms and restrictions set forth in the XERC LLC Agreement). Alternatively, X-Energy, Inc. may instead authorize a cash payment equal to a volume weighted average market prices of one share of X-Energy, Inc. Class A common stock for each unit redeemed (subject to customary adjustments, including for stock splits, stock dividends and similar events affecting the X-Energy, Inc. Class A common stock). If X-Energy, Inc. decides to make a cash payment, the Member has the option to rescind its redemption request within a specified time period. Upon the exercise of the redemption right, the redeeming member will surrender its units for cancellation. The XERC LLC Agreement requires that X-Energy, Inc. contribute cash or shares of X-Energy, Inc. Class A common stock to XERC in exchange for an amount of units that will be issued to us equal to the number of units redeemed from the Member. XERC will then distribute the cash or shares of X-Energy, Inc. Class A common stock to such Member to complete the redemption. In the event of such election by a Member, X-Energy, Inc. may, at its option, effect a direct exchange of cash or X-Energy, Inc. Class A common stock for such units in lieu of such a redemption. Whether by redemption or exchange, we are obligated to ensure that at all times the number of Common Units that X-Energy, Inc. own equals the number of shares of X-Energy, Inc. Class A common stock issued by X-Energy, Inc. (subject to certain exceptions for treasury shares and shares underlying certain convertible or exchangeable securities). Shares of X-Energy, Inc. Class B common stock will be cancelled on a one-to-one basis if we, at the election of a Member, redeem or exchange units of such Member pursuant to the terms of the XERC LLC Agreement.
Issuance of Equity-based Compensation. X-Energy, Inc. may implement equity compensation plans and any actions taken under such equity compensation plans (such as the grant or exercise of options to acquire shares of X-Energy, Inc. Class A common stock), whether taken with respect to or by an employee or other service provider of X-Energy, Inc., XERC or its subsidiaries, in a manner determined by X-Energy, Inc., in accordance with the initial implementation guidelines attached to the XERC LLC Agreement, which may be amended from time to time. X-Energy, Inc. may amend the XERC LLC Agreement (including the initial implementation guidelines attached thereto) as necessary or advisable in its sole discretion in connection with the adoption, implementation, modification or termination of an equity compensation plan. In the event of such an amendment, XERC will provide notice of such amendment to the Members. XERC is expressly authorized to issue units (i) in accordance with the terms of any equity compensation plans or (ii) in an amount equal to the number of shares of Class A common stock issued pursuant to any such equity compensation plans, without any further act, approval or vote of any Member or any other Persons.
Maintenance of One-to-One Ratios. X-Energy, Inc.’s Amended and Restated Certificate of Incorporation and the XERC LLC Agreement will require that X-Energy, Inc. and XERC, respectively, at all times maintain (i) a one-to-one ratio between the number of Common Units owned by X-Energy, Inc., directly or indirectly, and the aggregate number of outstanding shares of X-Energy, Inc. Class A common stock, and (ii) a one-to-one ratio between the number of Common Units owned by each Member (other than X-Energy, Inc. and its subsidiaries), directly or indirectly, and the aggregate number of outstanding shares of X-Energy, Inc. Class B common stock owned by such Member.
Transfer Restrictions. The XERC LLC Agreement generally does not permit transfers of Common Units, by Members, subject to limited exceptions. Any transferee of Common Units must execute the XERC LLC Agreement and any other agreements executed by the holders of Common Units and relating to such Common Units.
Dissolution. The XERC LLC Agreement provides that the decision of X-Energy, Inc. with the approval of a majority of the equity interests (including, but not limited to, Common Units) then outstanding (excluding all units held directly or indirectly by X-Energy, Inc.) will be required to voluntarily dissolve XERC. In addition to a voluntary dissolution, XERC will be dissolved under Section 18-801(4) of the DGCL because all members withdraw/resign (unless XERC is continued without dissolution pursuant thereto) or pursuant to Section 18-802 of the DGCL by operation of law, including entry of a decree of judicial dissolution.
Confidentiality. Each Member (other than X-Energy, Inc.) agrees to hold confidential information in confidence and may not disclose or use such information except as otherwise authorized separately in writing by X-Energy, Inc. This obligation excludes information that (i) is, or becomes, generally available to the public other than as a direct or indirect result of a disclosure by such Member or its affiliates or representatives; (ii) is, or becomes, available to such Member from a source other than X-Energy, Inc., XERC or their respective representatives; (iii) is approved for release by written authorization of the chief executive officer, chief
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financial officer or general counsel of X-Energy, Inc. or any other officer designated by X-Energy, Inc.; or (iv) is or becomes independently developed by such Member or its respective representatives without use of or reference to the confidential information.
Indemnification and Exculpation. The XERC LLC Agreement provides for indemnification for all expenses, liabilities and losses (including attorneys’ fees, judgments, fines, excise taxes or penalties) reasonably incurred or suffered by reason of the fact that such person is or was a Member or an affiliate thereof or is or was serving as manager or a director, officer, employee, advisor, attorney, accountant or other agent or representative of the manager, the Company Representative (as such term is defined in the XERC LLC Agreement), or a director, manager, officer, employee, advisor, attorney, accountant or other agent or representative of XERC or is or was serving at the request of XERC as a manager, officer, director, principal, member, employee, advisor, attorney, accountant or other agent or representative of another person; provided, however, that no indemnified person shall be indemnified for any expenses, liabilities and losses suffered that are attributable to such indemnified person’s or its affiliates’ fraud, willful misconduct or knowing violation of law or for any present or future breaches of any representations, warranties or covenants by such indemnified person or its affiliates contained in the XERC LLC Agreement or in other agreements with XERC.
Amendments. The XERC LLC Agreement may be amended or modified (including by means of merger, consolidation or other business combination to which XERC is a party) upon the prior written consent of X-Energy, Inc. together with the prior written consent of the holders of a majority of the equity interests (including, but not limited to, Common Units) then outstanding (excluding all units held directly or indirectly by X-Energy, Inc.); provided, that no alteration, modification or amendment shall be effective until written notice has been provided to the Members. Notwithstanding the foregoing, no amendment to any of the terms and conditions of the XERC LLC Agreement that expressly require the approval or action of certain persons may be made without obtaining the consent of the requisite number or specified percentage of such persons who are entitled to approve or take action on such matter. Additionally, no alteration, modification or amendment may be made to any of the terms and conditions of the XERC LLC Agreement that would (A) reduce the amounts distributable to a Member in a manner that is not pro rata with respect to all Members, (B) modify the limited liability of any Member or increase the liabilities of such Member hereunder, (C) otherwise materially and adversely affect a holder of units in a manner materially disproportionate to any other holder of units or remove a right or privilege granted to a Member (other than amendments, modifications and waivers necessary to implement the provisions permitting substitution or admission of Members) or (D) alter or change any rights, preferences or privileges of any units in a manner that is different or prejudicial relative to any other units in the same class of unit or materially and adversely affect the rights of any Member, in each case without the prior written consent of such Member or holder of units.
Tax Receivable Agreement
As a result of our organizational structure, we expect to obtain (a) tax basis adjustments, including an increase in our allocable share of existing tax basis, expected to be obtained by us resulting from (i) X-energy Inc’s acquisition of Common Units in connection with this Offering, including the contribution of Common Units from the Continuing Equity Owners, (ii) any future redemptions or exchanges of Common Units from the TRA Holders; (iii) certain distributions (or deemed distributions) by XERC; and (iv) payments made under the Tax Receivable Agreement, (such tax basis adjustments, the “Basis Adjustments”); and (b) deductions attributable to imputed interest and other payments of interest pursuant to the Tax Receivable Agreement (such deductions, the “Interest Deductions”). The parties intend to treat each redemption or exchange of Common Units pursuant to the XERC LLC Agreement as our direct purchase of Common Units from a Common Unit holder for U.S. federal income and other applicable tax purposes, regardless of whether such Common Units are surrendered by a Common Unit holder to XERC for redemption, or, to the extent there is cash available from a contemporaneous public offering or private sale of our Common Stock by us and we so authorize, sold directly to us. Any Basis Adjustments and Interest Deductions may have the effect of reducing the amount of taxes that we would otherwise pay in the future to various tax authorities. The Basis Adjustments and Interest Deductions may also decrease gains (or increase losses) on future dispositions of certain assets to the extent tax basis is allocated to those assets.
In connection with the closing of this offering, we will enter into a Tax Receivable Agreement with XERC and the TRA Holders. The Tax Receivable Agreement will provide for the payment by us to the TRA Holders
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of 85% of the amount of cash tax savings, if any, that we actually realize (or in some circumstances are deemed to realize) as a result of the Basis Adjustments and Interest Deductions, including those resulting from payments pursuant to the Tax Receivable Agreement. XERC and its applicable subsidiaries will have an election under Section 754 of the U.S. Internal Revenue Code of 1986, as amended (the “Code”), in effect for each taxable year in which a redemption or exchange of Common Units for our Class A common stock or cash occurs. Assuming no material changes in the relevant tax law and that we earn sufficient taxable income to realize all tax benefits that are subject to the Tax Receivable Agreement, we expect that the tax savings associated with the (i) Basis Adjustments, and (ii) Interest Deductions would aggregate to approximately $ million over years from the date of this offering based on a $ per share trading price of our Class A common stock and assuming all future redemptions or exchanges would occur on the date of this offering at the same assumed price per share. Under such scenario, assuming future payments are made on the due date (with extension) of each relevant U.S. federal income tax return, we would be required to pay approximately 85% of such amount, or approximately $ million, over the -year period from the date of this offering, and we would benefit from the remaining 15% of the tax benefits. These Tax Receivable Agreement payments are not conditioned upon any continued ownership interest in either XERC or us by any TRA Holder. The rights of each TRA Holder under the Tax Receivable Agreement are assignable regardless of whether the underlying Common Units are also assigned. In general, the TRA Holders’ rights under the Tax Receivable Agreement may not be assigned, sold, pledged or otherwise alienated to any person, other than certain permitted transferees, without our consent and such person becoming a party to the Tax Receivable Agreement and agreeing to succeed to the applicable TRA Holder’s interest therein.
The actual Basis Adjustments and Interest Deductions, as well as any amounts paid to the TRA Holders under the Tax Receivable Agreement, will vary depending on a number of factors, including:
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the price of our Class A common stock at the time of redemptions or exchanges — the Basis Adjustments, as well as any related increase in any tax deductions, are directly related to the price of our Class A common stock at the time of each redemption or exchange
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the timing of any subsequent redemptions or exchanges — for instance, the increase in any tax deductions will vary depending on the fair value, which may fluctuate over time, of the depreciable or amortizable assets of XERC and certain of its direct and indirect subsidiaries at the time of each redemption, exchange or distribution (or deemed distribution) as well as the amount of remaining existing tax basis at the time of such redemption, exchange or distribution (or deemed distribution);
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the extent to which such redemptions or exchanges are taxable — if a redemption or exchange is not taxable for any reason, certain of the increased tax deductions will not be available;
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the extent to which such Basis Adjustments are immediately deductible — we may be permitted to immediately expense a portion of the Basis Adjustments attributable to a redemption or exchange, which could significantly accelerate the timing of our realization of the associated tax benefits. Under the XERC LLC Agreement, the determination of whether to immediately expense such Basis Adjustments will be made in our sole discretion; and
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the amount and timing of our income — the Tax Receivable Agreement generally will require us to pay % of the amount of cash tax savings as and when such cash tax savings are treated as realized under the terms of the Tax Receivable Agreement. If we do not have sufficient taxable income to realize any of the applicable tax benefits, we generally will not be required (absent circumstances requiring an early termination payment or a change of control requiring the use of certain calculation assumptions) to make payments under the Tax Receivable Agreement for that taxable year because no tax benefits will have been actually realized. However, any tax benefits that do not result in realized tax benefits in a given taxable year may generate tax attributes that may be used to generate tax benefits in previous or future taxable years. The use of any such tax attributes will result in payments under the Tax Receivable Agreement.
For purposes of the Tax Receivable Agreement, cash savings in income taxes will be computed by comparing our actual income tax liability to the amount of such taxes that we would have been required to pay had there been no Basis Adjustments and Interest Deductions; provided that, for purposes of determining cash savings with respect to state and local income taxes an assumed tax rate will be used. The Tax Receivable Agreement will generally apply to each of our taxable years, beginning with the first taxable year ending after
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the completion of this offering. There is no maximum term for the Tax Receivable Agreement, although, as discussed further below, the Tax Receivable Agreement may be terminated by us pursuant to an early termination procedure or upon the occurrence of certain events, in each case, that requires us to pay the TRA Holders an agreed upon amount equal to the estimated present value of the remaining payments to be made under the agreement (calculated based on certain assumptions, including regarding tax rates and use of the Basis Adjustments and Interest Deductions).
The payment obligations under the Tax Receivable Agreement are obligations of us and not XERC. Although the actual timing and amount of any payments that may be made under the Tax Receivable Agreement will vary, it is expected that the payments that we may be required to make to the TRA Holders could be substantial. Any payments made by us to the TRA Holders under the Tax Receivable Agreement will generally reduce the amount of overall cash flow that might have otherwise been available to us and, to the extent that we are unable to make payments under the Tax Receivable Agreement for any reason, the unpaid amounts generally will be deferred and will accrue interest until paid by us; provided, however, that nonpayment for a specified period may constitute a material breach of a material obligation under the Tax Receivable Agreement and, therefore, may accelerate payments due under the Tax Receivable Agreement, which could be substantial. We anticipate funding ordinary course payments under the Tax Receivable Agreement from cash flow from operations of our subsidiaries, available cash or available borrowings under our existing credit facilities or any future debt agreements.
Decisions made by us in the course of running our business, such as with respect to mergers, asset sales, other forms of business combinations or other changes in control, may influence the timing and amount of payments that we are required to make to a TRA Holder under the Tax Receivable Agreement. For example, the earlier disposition of assets following an exchange or acquisition transaction will generally accelerate payments under the Tax Receivable Agreement and increase the present value of such payments.
The Tax Receivable Agreement provides that if (a) we materially breach any of our material obligations under the Tax Receivable Agreement or (b) we elect an early termination of the Tax Receivable Agreement, then our obligations, or our successor’s obligations, under the Tax Receivable Agreement would accelerate and become due and payable, based on certain assumptions, including an assumption that we would have sufficient taxable income to fully use all potential future tax benefits that are subject to the Tax Receivable Agreement. In those circumstances, TRA Holders would be deemed to exchange any remaining outstanding Common Units for our Class A common stock and the TRA Holders generally would be entitled to payments under the Tax Receivable Agreement resulting from such deemed exchanges. We may elect to completely terminate the Tax Receivable Agreement early only with the written approval of a majority of our “independent directors” (within the meaning of the rules of the Nasdaq). The amount due and payable in those circumstances is based on the present value (at a discount rate of SOFR plus 100 basis points) of projected future tax benefits that are based on certain assumptions, including an assumption that we would have sufficient taxable income to fully use all potential future tax benefits that are subject to the Tax Receivable Agreement. Based on such assumptions, if we were to exercise our termination right, or the Tax Receivable Agreement is otherwise terminated, immediately following the consummation of this offering, the aggregate amount of the termination payments would be approximately $ million. In addition, upon a change of control our (or our successor’s) payments under the Tax Receivable Agreement for each taxable year after any such event would be based on certain assumptions, including an assumption that we would have sufficient taxable income to fully use all potential tax benefits that are subject to the Tax Receivable Agreement.
As a result of the foregoing, we could be required to make an immediate cash payment, possibly significantly in advance of the actual realization, if any, of such future cash tax savings. We also could be required to make cash payments to the TRA Holders that are greater than 85% of the actual benefits we ultimately realize in respect of the tax benefits that are subject to the Tax Receivable Agreement. In these situations, our obligations under the Tax Receivable Agreement could have a substantial negative impact on our liquidity and could have the effect of deferring or preventing certain mergers, asset sales, other forms of business combination, or other changes of control. There can be no assurance that we will be able to finance our obligations under the Tax Receivable Agreement.
Payments under the Tax Receivable Agreement will be based on the tax reporting positions that we determine, which are complex and factual in nature, and the Internal Revenue Service or another taxing authority may challenge all or any part of the Basis Adjustments, as well as other tax positions that we take,
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and a court may sustain such a challenge. We will not be reimbursed for any cash payments previously made to the TRA Holders pursuant to the Tax Receivable Agreement if any tax benefits initially claimed by us are subsequently challenged by a taxing authority and ultimately disallowed. Instead, any excess cash payments made by us to a TRA Holder will be netted against future cash payments, if any, we might otherwise be required to make under the terms of the Tax Receivable Agreement to such TRA Holders. However, a challenge to any tax benefits initially claimed by us may not arise for a number of years following the initial time of such payment or, even if challenged early, such excess cash payment may be greater than the amount of future cash payments, if any, we might otherwise be required to make under the terms of the Tax Receivable Agreement and, as a result, there might not be future cash payments from which to net against. As a result, it is possible that we could make cash payments under the Tax Receivable Agreement that are substantially greater than 85% of our actual cash tax savings.
We will have full responsibility for, and sole discretion over, all our and XERC’s tax matters, including the filing and amendment of all tax returns and claims for refund and defense of all tax contests, subject to certain participation and approval rights held by certain TRA Holders. If the outcome of any challenge to all or part of the Basis Adjustments, Interest Deductions or other tax benefits we claim would reasonably be expected to materially affect a TRA Holder’s rights and obligations under the Tax Receivable Agreement, then we will not be permitted to settle such challenge without the consent (not to be unreasonably withheld or delayed) of certain TRA Holders. The interests of such TRA Holders in any such challenge may differ from or conflict with our and our investors’ interests, and such TRA Holders may exercise their consent rights relating to any such challenge in a manner adverse to our and our investors’ interests.
Under the Tax Receivable Agreement, we are required to provide each TRA Holder that holds an interest in the Tax Receivable Agreement and to which a tax benefit or detriment is attributable with a schedule showing the calculation of payments that are due under the Tax Receivable Agreement with respect to each taxable year with respect to which a payment obligation to such holder arises within days after filing our U.S. federal income tax return for such taxable year. This calculation will be based upon the advice of our tax advisors. Payments are generally due under the Tax Receivable Agreement within a specified period of time following the filing of our tax return for the taxable year with respect to which the payment obligation arises, although interest on such payments will begin to accrue at a rate of SOFR plus 100 basis points from the due date (without extensions) of such tax return. Some late payments that may be made under the Tax Receivable Agreement will continue to accrue interest at a rate of SOFR plus 500 basis points until such payments are made, including any late payments that we may subsequently make because we did not have enough available cash to satisfy our payment obligations at the time at which they originally arose.
Shareholder Rights Agreement — Rights of Appointment and Registration Rights
We have entered into a shareholder rights agreement with certain X-energy Members (the “Shareholder Rights Agreement”) pursuant to which certain X-energy Members have the right to designate nominees to our board of directors, subject to the maintenance of specified ownership requirements. Other than the Shareholder Rights Agreement, we are not a party to, and are not aware of, any voting agreements currently in effect among our shareholders.
We have also granted certain X-energy Members registration rights as described below. The Shareholder Rights Agreement provides that we will pay certain expenses relating to such registrations and indemnify certain X-energy Members against certain liabilities that may arise under the Securities Act. The Shareholder Rights Agreement will terminate when such X-energy Members no longer own any of the LLC Units.
Historical Transactions with Affiliates
In the normal course of business, we enter into transactions with related parties in which certain of our affiliates hold financial interests, which are described in more detail below.
Our Relationship with Intuitive Machines
Kamal Ghaffarian, the founder and executive chairman of X-energy, is a co-founder and executive chairman of Intuitive Machines, Inc. (“Intuitive Machines”). In 2021, X-energy and Intuitive Machines formed a joint venture, IX, LLC, to pursue nuclear space propulsion and surface power systems in support of
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future space exploration goals. Intuitive Machines currently holds 510 membership unit interests of IX, LLC, representing 51% of the issued and outstanding membership unit interests of IX, LLC. X-energy currently holds 490 membership unit interests of IX, LLC, representing 49% of the issued and outstanding membership unit interests of IX, LLC. During the years ended December 2024 and 2023, revenues associated with this joint venture were $0.2 million and $1.4 million, direct costs were $0.1 million and $0.8 million, and general and administrative expenses were $0.1 million and $0.4 million, respectively. During nine months ended September 30, 2025 and 2024, revenues associated with this joint venture were $0.8 million and immaterial, direct costs were $0.6 million and zero, and general and administrative expenses were $0.1 million and zero, respectively.
Our Relationship with IBX
Kamal Ghaffarian, the founder and executive chairman of X-energy, is a co-founder and current member of management of IBX, LLC (“IBX”), an investment firm. X-energy relies on IBX for the provision of general and administrative services in the day-to-day operation of its business. These expenses include, among others, fees for the provision of capital raise and proposal services. As such, expenses incurred in relation to IBX are incurred in the normal course of business and amounts are settled under normal business terms. For the fiscal years ended December 31, 2024 and 2023, these costs were $0.8 million and $1.2 million, respectively. For the nine months ended September 30, 2025 and 2024, these costs were $0.1 million and $0.8 million, respectively.
Our Professional Services Agreement with Kamal Ghaffarian
In January 2020, X-energy entered into a professional services agreement with Kamal Ghaffarian, its founder and executive chairman, pursuant to which Mr. Ghaffarian agreed to provide professional consulting and advising services to X-energy for a period of three years beginning January 1, 2020 for a fixed fee of $0.08 million per quarter. Beginning January 2022, the fee was increased to $0.10 million per quarter. The agreement shall continue in effect until the first of the following to occur: (a) X-energy notifies Mr. Ghaffarian that the services have been completed, (b) the sum of all awarded task orders has been reached and has not been increased in accordance with the agreement or (c) the agreement has been terminated in accordance with its terms. X-energy extended this agreement for an additional one year terms on January 1, 2023, 2024 and 2025. For the fiscal years ended December 31, 2024 and 2023, the Company incurred $0.4 million and $0.4 million, respectively, of consulting fees in connection with this agreement. For the nine months ended September 2025 and 2024, the Company incurred $0.3 million and $0.2 million, respectively, of consulting fees in connection with this agreement. The Company may determine after the offering to discontinue this agreement.
Our Agreement with Aerotherm
Martin Van Staden, our Senior Vice President and Chief Technology Officer, is the president, founder and principal shareholder of Aerotherm, Inc. (“Aerotherm”). X-energy entered into a contract to receive consulting services from Aerotherm. During the years ended December 31, 2024 and 2023, the Company incurred subcontracting costs to Aerotherm, Inc. in the amount of $0.6 million and $0.9 million, respectively, for these services. During the nine months ended September 2025 and 2024, the Company incurred subcontracting costs to Aerotherm, Inc. in the amount of $0.1 million and $0.5 million, respectively, for these services.
Our Agreement with Hatch
Hatch Associates Consultants, Inc (“Hatch”) is a unitholder of XERC. The Company entered into an agreement to receive support services related to its U.S. and international engineering and development activities, including services related to the DOE ARDP from Hatch. The services include, but are not limited to, project management, quality assurance management, cost control management and program risk management. During the years ended December 31, 2024, and 2023, the Company incurred costs to Hatch in the amount of $7.4 million and $33.5 million, respectively, for these services. As of December 31, 2024 and 2023, $4.5 million and $7.1 million due to Hatch Associates Consultants, Inc. was included within our financial statements as due to related parties. During the nine months ended September 30, 2025, and 2024, the
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Company incurred costs to Hatch in the amount of $4.6 million and $7.1 million, respectively, for these services. As of September 30, 2025, and 2024, $0.4 million and $5.7 million due to Hatch Associates Consultants, Inc. was included within our financial statements as due to related parties.
Our Agreement with Zachry Nuclear
Zachry Nuclear Engineering, Inc (“Zachry Nuclear”) is a unitholder of XERC. The Company entered into an agreement to receive support services related to the DOE ARDP from Zachry Nuclear. The services include, but are not limited to, site design and pre-construction activities, such as safety and licensing analysis support, engineering management and oversight, and system design services. During the years ended December 31, 2024 and 2023, the Company incurred costs to Zachry Nuclear in the amount of $1.0 million and $7.7 million, respectively, for these services. As of December 31, 2024 and 2023, an immaterial amount and $1.5 million due to Zachry Nuclear was included within our financial statements as due to related parties, respectively. During the nine months ended September 30, 2025, and 2024, the Company incurred costs to Zachry Nuclear in the amount of an immaterial amount and $1.0 million, respectively, for these services. As of September 30, 2025 and 2024, zero and $0.4 million due to Zachry Nuclear was included within our financial statements as due to related parties, respectively.
Our Agreement with Burns & McDonnell
Burns & McDonnell Engineering Company, Inc (“Burns & McDonnell”) is a unitholder of XERC. The Company entered into an agreement to receive support services related to the DOE ARDP from Burns & McDonnell. The services include, but are not limited to, preliminary design support and pre-construction support. During the years ended December 31, 2024 and 2023, the Company incurred costs to Burns & McDonnell in the amount of $2.8 million and $12.7 million, respectively, for these services. As of December 31, 2024 and 2023, $0.1 million and $2.2 million due to Burns & McDonnell was included within our financial statements as due to related parties, respectively. During the nine months ended September 30, 2025 and 2024, the Company incurred costs to Burns & McDonnell in the amount of $1.0 million and $2.7 million, respectively, for these services. As of September 30, 2025 and 2024, $0.5 million and $0.6 million due to Burns & McDonnell was included within our financial statements as due to related parties, respectively.
Our Relationship with Curtiss-Wright Corporation
Curtiss-Wright Corporation is a unitholder of XERC. During the years ended December 31, 2024 and 2023, the Company incurred subcontracting costs to Curtiss-Wright Corporation, Inc. in the amount of $4.2 million and $15.0 million, respectively, related to the DOE ARDP. As of December 31, 2024 and 2023, $0.5 million and $3.4 million was due to Curtiss-Wright Corporation, Inc. and was included within our financial statements as due to related parties, respectively. During the nine months ended September 30, 2025 and 2024, the Company incurred subcontracting costs to Curtiss-Wright Corporation, Inc. in the amount of $3.6 million and $3.9 million, respectively, related to the DOE ARDP. As of September 30, 2025 and 2024, $0.5 million and $0.3 million was due to Curtiss-Wright Corporation, Inc. and was included within our financial statements as due to related parties, respectively.
Our Relationship with The Dow Chemical Company
Dow is a unitholder and warrantholder of XERC. During 2022, the Company entered into a non-binding letter of intent with Dow to develop a small modular reactor at one of Dow’s U.S. Gulf Coast sites. In the first quarter of 2023, the Company entered into a joint development agreement with Dow. In the first quarter of 2025, the Company entered into a master project development agreement and a commercial cooperation agreement with Dow. During the years ended December 31, 2024 and 2023, the Company incurred costs to Dow in the amount of $5.8 million and zero, respectively. As of December 31, 2024 and 2023, $2.3 million and zero due to Dow was included within due to related parties. For the years ended December 31, 2024 and 2023, the revenues associated with these contracts are $26.8 million and $5.9 million, respectively. As of December 31, 2024 and 2023, $15.8 million and $3.5 million due from Dow was included within our financial statements as due from related parties, respectively. For the nine months ended September 30, 2025 and 2024, the revenues associated with these contracts are $6.3 million and $18.7 million, respectively. As of
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September 30, 2025 and 2024, $2.6 million and $4.7 million due to Dow was included within our financial statements as due to related parties, respectively.
Our Relationship with Amazon
Amazon.com NV Investment Holdings LLC (“Amazon”) is a unitholder and warrantholder of XERC. In 2024, the Company entered into a project with Amazon to provide design and engineering services. During the year ended December 31, 2024, the Company recorded $0.7 million within revenue associated with this project. As of December 31, 2024, $0.6 million associated with deferred revenue for this project was included within due to related parties.
During each of the nine months ended September 30, 2025 and 2024, the Company recorded $0.6 million within revenue associated with this project. As of September 30, 2025 and 2024, an immaterial amount and $0.6 million associated with deferred revenue for this project was included within due to related parties.
Our Relationship with Centrica
Centrica is the largest provider of energy services across the U.K. and owns a 20% stake in the full fleet of operating nuclear reactors in the country. In September 2025, X-energy and Centrica signed a Joint Development Agreement (JDA) dedicated to building and operating Xe-100 reactors in the U.K. Subject to securing appropriate permissions and licenses, the first electricity generation is expected to be in the mid-2030s.
Our Agreement with Desbuild Construction
Nick Ghaffarian, the brother of Kam Ghaffarian, is the owner of Desbuild Construction, Inc. (“Desbuild Construction”). During 2022, X-energy engaged Desbuild Construction for construction-related services for X-energy’s training facility in Frederick, Maryland (the “Frederick Facility”). The services included, but were not limited to, demolition and design services for the build out of the Frederick Facility. In addition, in January 2023, X-energy entered into another agreement with Desbuild Construction, pursuant to which Desbuild Construction agreed to remodel the Frederick Facility for a fixed fee of $1.4 million. X-energy makes payments in installments to Desbuild Construction upon completion of the milestones specified in the agreement. For the fiscal years ended December 31, 2024 and 2023, the Company recorded $0.7 million and $0.8 million, respectively, associated with these services as leasehold improvements within property and equipment, net. For the nine months ended September 30, 2025 and 2024, the Company recorded $0.6 million and $0.7 million, respectively, associated with these services as leasehold improvements within property and equipment, net. Refer to Note 5 — Government Grants for additional information regarding grants received for these costs.
Our Relationship with Chris Ginther
Christopher F. Ginther, a member of X-energy’s board of directors, was an Executive Vice President of OPG. In 2022, X-energy and OPG entered into a framework agreement to work exclusively with one another with respect to advanced nuclear power industrial applications in Ontario, Canada, and to co-market and advance the Xe-100 as the nuclear technology of choice for industrial applications throughout Canada. OPG will be the operator of any Xe-100 facilities that are deployed under this agreement. OPG is also an equity investor in X-energy.
We also have a project management consulting agreement with Outpost Consultants, in which Ginther is an owner.
Policies and Procedures for Related Persons Transactions
The Board of X-Energy, Inc. will adopt a formal written related person transaction policy that will be effective upon the Closing. Such policy will provide that X-energy’s executive officers, directors, director nominees, any member of the immediate family of any of the foregoing persons, or a security holder known to be a beneficial owner of more than 5% of any class of X-energy’s voting securities, are not permitted to enter into a “related person transaction” (as defined under Item 404 of Regulation S-K) with X-energy without the approval of X-energy’s audit committee, subject to certain exceptions.
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PRINCIPAL STOCKHOLDERS
The following table sets forth information regarding the beneficial ownership of our Class A common stock and Class B common stock by (1) each person known to us to beneficially own more than 5% of our voting securities, (2) each of our directors, (3) each of our named executive officers and (4) all directors and executive officers as a group.
The number of shares of Class A common stock and Class B common stock outstanding and percentage of beneficial ownership before and after this offering are based on (i) the number of shares and Common Units to be issued and outstanding immediately prior to and after the consummation of this offering, after giving effect to the Transactions and (ii) an assumed initial public offering price of $ per share (the midpoint of the estimated price range set forth on the cover page of this prospectus). See “Organizational Structure.”.
Beneficial ownership of Class A common stock and Class B common stock is determined in accordance with the rules of the SEC. In accordance with the rules of the SEC, beneficial ownership includes voting or investment power with respect to securities and includes shares issuable pursuant to exchange or conversion rights that are exercisable within 60 days of the date of this prospectus.
To our knowledge, except as indicated in the footnotes to this table and pursuant to applicable community property laws, the persons named in the table have sole voting and investment power with respect to all shares of common stock.
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Class A common stock
Beneficially Owned |
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Beneficially Owned |
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Beneficially
Owned Prior to the Offering |
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After the
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After the
Offering Assuming Underwriters’ Option is Exercised in Full |
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Beneficially
Owned Prior to the Offering |
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After the
Offering Assuming Underwriters’ Option is Not Exercised |
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After the
Offering Assuming Underwriters’ Option is Exercised in Full |
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Name of Beneficial Owner(1)
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Greater than 5% Stockholders
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| Named Executive Officers: | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
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J. Clay Sell
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| Directors: | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
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Dr. Kamal Ghaffarian
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Christopher F. Ginther
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Gregory J. Goff
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Kathleen W. Hyle
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David Kaplan
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Allyson Satin
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Edward Sonnenschein
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Michael J. Wallace
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Directors and executive officers as a group (14 persons)
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*
Less than 1% of common stock outstanding.
(1)
Unless otherwise indicated in the below, the address of each of the individuals named above is: .
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DESCRIPTION OF CAPITAL STOCK
The following is a description of the material terms of, and is qualified in its entirety by, our amended and restated certificate of incorporation and amended and restated bylaws, each of which will be in effect upon the consummation of this offering, the forms of which are filed as exhibits to the registration statement of which this prospectus is a part.
Our purpose is to engage in any lawful act or activity for which corporations may now or hereafter be organized under the DGCL. Upon consummation of this offering, our authorized capital stock will consist of shares of common stock, par value $0.0001 per share, and shares of preferred stock. Immediately following the completion of this offering, there are expected to be outstanding shares of common stock.
Common Stock
Class A common stock
Voting rights. Each holder of Class A common stock is entitled to one vote for each share of Class A common stock held of record in person, virtually or by proxy on all matters submitted to a vote of the holders of Class A common stock, whether voting separately as a class or otherwise.
Dividend rights. Subject to applicable law and the rights and preferences of any holders of any outstanding series of Preferred Stock or any class or series of stock having a preference over or the right to participate with the Class A common stock with respect to the payment of dividends, holders of Class A common stock, as such, shall be entitled to the payment of dividends on the Class A common stock when, as and if declared by the Board in accordance with applicable law.
The payment of future dividends on the shares of Class A common stock will depend on the financial condition of after the completion of this offering, and subject to the discretion of the Board. There can be no guarantee that cash dividends will be declared. The ability of to declare dividends may be limited by the terms and conditions of other financing and other agreements entered into by or any of its subsidiaries from time to time.
Rights upon liquidation. In the event of liquidation, dissolution or winding up of the affairs of, whether voluntary or involuntary, after payment or provision for payment of the debts and other liabilities of and after making provisions for preferential and other amounts, if any, to which the holders of Preferred Stock or any class or series of stock having a preference over or the right to participate with the Class A common stock with respect to payments in liquidation shall be entitled, the remaining assets and funds of available for distribution shall be divided among and paid ratably to the holders of all outstanding shares of Common Stock in proportion to the number of shares held by each such stockholder.
Other rights. The holders of Class A common stock have no pre-emptive or conversion rights or other subscription rights. There are no redemption or sinking fund provisions applicable to the Class A common stock. The rights, preferences and privileges of holders of the Class A common stock will be subject to those of the holders of any shares of the Preferred Stock that may issue in the future.
Class B common stock
Voting rights. Each holder of Class B common stock is entitled to one vote for each share of Class B common stock held of record in person, virtually or by proxy on all matters submitted to a vote of the holders of Class B common stock, whether voting separately as a class or otherwise.
Dividend rights. Other than in connection with a dividend declared by the Board in connection with a “poison pill” or similar stockholder rights plan, dividends shall not be declared or paid on the Class B common stock and the holders of shares of Class B common stock shall have no right to receive dividends in respect of such shares of Class B common stock.
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Rights upon liquidation. Each holder of shares of Class B common stock shall be entitled to receive $0.0001 per share of Class B common stock owned of record by such holder on the record date for such distribution, and upon receiving such amount, the holders of shares of Class B common stock, in their capacity as such, shall not be entitled to receive any other assets or funds of.
Permitted Transfers. From and after the effectiveness of the Proposed Certificate of Incorporation (the “Charter Effective Time”), shares of Class B common stock may be issued only to, and registered only in the name of, the X-energy Members, their respective successors and assigns and their respective permitted transferees (the X-energy Members, together with all such subsequent successors, assigns and permitted transferees, collectively, the “Permitted Class B Owners”), and the aggregate number of shares of Class B common stock at any time registered in the name of each such Permitted Class B Owner must be equal to the aggregate number of X-energy Common Units held of record at such time by such Permitted Class B Owner under the XERC LLC Agreement. A Permitted Class B Owner may transfer or assign shares of Class B common stock (or any legal or beneficial interest in such shares) (directly or indirectly, including by operation of law) only to a permitted transferee of such holder or to a non-permitted transferee with the approval in advance and in writing by X-energy, and only if such holder also simultaneously transfers, in each case, an equal number of such holder’s X-energy Common Units to such permitted transferee or such non-permitted transferee, as applicable, in compliance with the XERC LLC Agreement. Permitted transfers include transfers pursuant to certain redemption or direct exchange scenarios, a transfer by a Permitted Class B Holder to the Company or any of its subsidiaries, or to an affiliate of such Permitted Class B Holder, in each case subject to and in compliance with the XERC LLC Agreement.
Cancellation of Class B Common Stock. A holder of Class B common stock may surrender shares of Class B common stock to X-energy for cancellation for no consideration at any time. Shares of Class B common stock are automatically transferred to X-Energy, Inc. upon the redemption or exchange of their Common Units pursuant to the terms of the XERC LLC Agreement and will be canceled and may not be reissued. Following the surrender or other acquisition of any shares of Class B common stock to X-energy or by X-energy, X-energy will take all actions necessary to cancel and retire such shares and such shares shall not be re-issued by X-energy.
Permitted Transfers. The Board (including a majority of the directors who are disinterested with respect to the relevant transaction serving on the Board at such time) may, to the extent permitted by law, from time to time establish, modify, amend or rescind, by bylaw or otherwise, regulations and procedures not inconsistent with the provisions described for determining whether any transfer or acquisition of shares of Class B common stock would violate the restrictions described and for the orderly application, administration and implementation of the provisions of the Proposed Certificate of Incorporation.
Preferred Stock
The Proposed Certificate of Incorporation will authorize the board of directors of to establish one or more series of Preferred Stock. Unless required by law or any stock exchange, the authorized shares of Preferred Stock will be available for issuance without further action by the holders of Common Stock.
The Board has the discretion to determine the powers, preferences and relative, participating, optional and other special rights, including voting rights, dividend rights, conversion rights, redemption privileges and liquidation preferences, of each series of Preferred Stock. The issuance of Preferred Stock may have the effect of delaying, deferring or preventing a change in control of without further action by the stockholders. Additionally, the issuance of Preferred Stock may adversely affect the holders of the Common Stock by restricting dividends on the Common Stock, diluting the voting power of the Common Stock or subordinating the liquidation rights of the Common Stock. As a result of these or other factors, the issuance of Preferred Stock could have an adverse impact on the market price of the Common Stock.
Anti-Takeover Effects of Our Amended and Restated Certificate of Incorporation and Amended and Restated Bylaws and Certain Provisions of Delaware Law
The provisions of the Proposed Certificate of Incorporation, the Proposed Bylaws and the DGCL summarized below may have an anti-takeover effect and may delay, defer or prevent a tender offer or takeover
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attempt that you might consider in your best interest, including an attempt that might result in your receipt of a premium over the market price for your shares of Class A common stock.
The Proposed Certificate of Incorporation and Proposed Bylaws contain certain provisions that are intended to enhance the likelihood of continuity and stability in the composition of the Board and that may have the effect of delaying, deferring or preventing a future takeover or change in control unless such takeover or change in control is approved by such board of directors.
These provisions include:
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Authorized but Unissued Capital Stock. Our authorized but unissued shares of Common Stock and Preferred Stock will be available for future issuance without stockholder approval. These additional shares may be utilized for a variety of corporate purposes, including future public offerings to raise additional capital, corporate acquisitions and employee benefit plans. The existence of authorized but unissued shares of Common Stock and Preferred Stock could render more difficult or discourage an attempt to obtain control of a majority of common stock by means of a proxy contest, tender offer, merger or otherwise.
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Director Designees; Classes of Directors. Pursuant to the Proposed Certificate of Incorporation, the directors of X-energy will be divided into three classes, with each class serving staggered three year terms. The existence of a classified board of directors could discourage a third party from making a tender offer or otherwise attempting to obtain control of us as it is more difficult and time consuming for stockholders to replace a majority of the directors on a classified board of directors.
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No Cumulative Voting for Directors. The DGCL provides that stockholders are not entitled to cumulate votes in the election of directors unless a corporation’s certificate of incorporation provides otherwise. The Proposed Certificate of Incorporation does not provide for cumulative voting. As a result, the holders of shares of Common Stock representing a majority of the voting power of all of the outstanding shares of our capital stock of will be able to elect all of the directors then standing for election.
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Quorum. The Proposed Bylaws will provide that at any meeting of the Board, a majority of the total number of directors then in office constitutes a quorum for the transaction of business.
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Action by Written Consent. The Proposed Certificate of Incorporation provides that any action required or permitted to be taken by the stockholders of must be effected at a duly called annual or special meeting of the stockholders of (and may not be taken by consent of the stockholders in lieu of a meeting). In addition to the foregoing, any action required or permitted to be taken by the holders of any series of Preferred Stock, voting separately as a series or separately as a class with one or more other such series, may be taken without a meeting, without prior notice and without a vote, to the extent expressly so provided by the applicable certificate of designation relating to such series of Preferred Stock, if a consent or consents in writing, setting forth the action so taken, shall be signed by the holders of outstanding shares of the relevant series of Preferred Stock having not less than the minimum number of votes that would be necessary to authorize or take such action at a meeting at which all shares entitled to vote thereon were present and voted and shall be delivered to in accordance with the applicable provisions of the DGCL.
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Special Meetings of Stockholders. Subject to the special rights of the holders of one or more series of Preferred Stock, special meetings of the stockholders of may be called, for any purpose or purposes, at any time only by or at the direction of (i) the board of directors, the chairperson of the board of directors, the chief executive officer or president, and (ii) special meetings of the stockholders of X-energy may not be called by the stockholders of X-energy or any other person.
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Advance Notice Procedures. The Proposed Bylaws establish an advance notice procedure for stockholder proposals to be brought before an annual meeting of our stockholders, and for stockholder nominations of persons for election to the board of directors of X-energy to be brought before an annual or special meeting of stockholders. Stockholders at an annual meeting will only be able to consider proposals or nominations specified in the notice of meeting or brought before the meeting by or at the direction of the board of directors of or by a stockholder who was a stockholder of record on the record date for the meeting, who is entitled to vote at the meeting and who has given the secretary
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of X-energy timely written notice, in proper form, of the stockholder’s intention to bring that business or nomination before the meeting. Although the Proposed Bylaws do not give the board of directors the power to approve or disapprove stockholder nominations of candidates or proposals regarding other business to be conducted at a special or annual meeting, as applicable, the Proposed Bylaws may have the effect of precluding the conduct of certain business at a meeting if the proper procedures are not followed or may discourage or deter a potential acquirer from conducting a solicitation of proxies to elect its own slate of directors or otherwise attempting to obtain control of X-energy.
Limitations on Liability and Indemnification of Officers and Directors
The DGCL authorizes corporations to limit or eliminate the personal liability of directors and officers to corporations and their stockholders for monetary damages for breaches of directors’ and officers’ fiduciary duties, subject to certain exceptions. The Proposed Certificate of Incorporation includes a provision that eliminates the personal liability of directors and officers for monetary damages for any breach of fiduciary duty as a director or officer, except to the extent such exemption from liability or limitation thereof is not permitted under the DGCL. The effect of these provisions is to eliminate the rights of X-energy and its stockholders, through stockholders’ derivative suits on X-energy’s behalf, to recover monetary damages from a director or officer for breach of fiduciary duty as a director or officer, including breaches resulting from grossly negligent behavior. However, exculpation does not apply to any director or officer if the director or officer has acted in bad faith, knowingly or intentionally violated the law, authorized illegal dividends or Redemptions or derived an improper benefit from such person’s actions as a director or officer.
The Proposed Bylaws provide that X-energy must indemnify and advance expenses to directors and officers to the fullest extent authorized by the DGCL. X-energy is also expressly authorized to carry directors’ and officers’ liability insurance providing indemnification for directors, officers and certain employees for some liabilities. X-energy believes that these indemnification and advancement provisions and insurance are useful to attract and retain qualified directors and executive officers.
The limitation of liability, indemnification and advancement provisions in the Proposed Certificate of Incorporation and the Proposed Bylaws may discourage stockholders from bringing a lawsuit against directors and officers for breach of their fiduciary duty. These provisions also may have the effect of reducing the likelihood of derivative litigation against directors and officers, even though such an action, if successful, might otherwise benefit X-energy and its stockholders. Your investment may be adversely affected to the extent X-energy pays the costs of settlement and damage awards against directors and officers pursuant to these indemnification provisions. X-energy believes that these provisions, liability insurance and any indemnity agreements that may be entered into are necessary to attract and retain talented and experienced directors and officers.
Insofar as indemnification for liabilities arising under the Securities Act may be permitted to our directors, officers and controlling persons pursuant to the foregoing provisions, or otherwise, we have been advised that in the opinion of the SEC such indemnification is against public policy as expressed in the Securities Act and is, therefore, unenforceable.
There is currently no pending material litigation or proceeding involving any of our respective directors, officers or employees for which indemnification is sought.
Transfer Agent and Registrar
The Transfer Agent and registrar for the shares of Common Stock will be .
Listing
We intend to apply to have our common stock listed on Nasdaq under the symbol “XE.”
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SHARES ELIGIBLE FOR FUTURE SALE
Prior to this offering, there has been no public market for shares of our Class A common stock. We cannot predict the effect, if any, future sales of shares of Class A common stock, or the availability for future sale of shares of Class A common stock, will have on the market price of shares of our Class A common stock prevailing from time to time. Future sales of substantial amounts of our Class A common stock in the public market (including shares of Class A common stock issuable upon redemption or exchange of Common Units of our Continuing Equity Owners) or the perception that such sales might occur may adversely affect market prices of our Class A common stock prevailing from time to time and could impair our future ability to raise capital through the sale of our equity or equity-related securities at a time and price that we deem appropriate. Furthermore, there may be sales of substantial amounts of our Class A common stock in the public market after the existing legal and contractual restrictions lapse. This may adversely affect the prevailing market price and our ability to raise equity capital in the future. See “Risk Factors — Risks Related to the Offering and Ownership of our Class A common stock — Sales, directly or indirectly, of a substantial amount of our Class A common stock in the public markets by our existing security holders may cause the price of our Class A common stock to decline.”
Upon completion of this offering, we will have a total of shares of our Class A common stock outstanding. Of the outstanding shares, the shares sold in this offering (or shares if the underwriters exercise in full their over-allotment option) will be freely tradable without restriction or further registration under the Securities Act, except that any shares held by our affiliates, as that term is defined under Rule 144, including our directors, executive officers and other affiliates (including our existing owners), may be sold only in compliance with the limitations described below.
In addition, each Common Unit held by our Continuing Equity Owners will be redeemable, at the election of each Continuing Equity Owner, for, at our election (determined solely by our independent directors (within the meaning of Nasdaq rules) who are disinterested), newly issued shares of our Class A common stock on a one-for-one basis or a cash payment equal to a volume weighted average market price of one share of Class A common stock for each Common Unit so redeemed, in each case, in accordance with the terms of the XERC LLC Agreement; provided that, at our election (determined solely by our independent directors (within the meaning of Nasdaq rules) who are disinterested), we may effect a direct exchange by X-Energy, Inc. of such Class A common stock or such cash, as applicable, for such Common Units. The Continuing Equity Owners may, subject to certain exceptions, exercise such redemption right for as long as their Common Units remain outstanding. See “Certain Relationships and Related Party Transactions — XERC LLC Agreement.” Upon consummation of the Transactions, our Continuing Equity Owners will hold Common Units, all of which will be exchangeable for shares of our Class A common stock. The shares of Class A common stock we issue upon such exchanges would be “restricted securities” as defined in Rule 144 unless we register such issuances.
Lock-up Agreements
We, our officers, and directors, and holders of substantially all of our shares of capital stock or other securities convertible into or exchangeable for shares of our capital stock outstanding upon consummation of this offering have agreed or will agree that, without the prior written consent of J.P. Morgan Securities LLC and , we and they will not, subject to certain exceptions, during the period ending 180 days after the date of this prospectus:
(i) offer, sell, contract to sell, pledge, grant any option to purchase, lend or otherwise dispose of any shares of our Class A common stock, or any options or warrants to purchase any shares of our Class A common stock, or any securities convertible into, or exchangeable for, or that represent the right to receive, shares of our Class A common stock; or
(ii) engage in any hedging or other transaction or arrangement (including, without limitation, any short sale or the purchase or sale of, or entry into, any put or call option, or combination thereof, forward, swap or any other derivative transaction or instrument, however described or defined) which is designed to, or which reasonably could be expected to lead to, or result in, a sale, loan, pledge or other disposition of shares of our Class A common stock or any securities convertible into or exercisable or exchangeable
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for shares of our Class A common stock, whether any transaction described above is to be settled by delivery of our Class A common stock or such other securities, in cash or otherwise.
Upon the expiration of the applicable lock-up periods, substantially all of the shares subject to such lock-up restrictions will become eligible for sale, subject to the limitations discussed above. See “Underwriting” for additional information.
In addition to the restrictions contained in the lock-up agreements described above, we have entered into agreements with certain security holders that contain market standoff provisions imposing restrictions on the ability of such security holders to offer, sell, or transfer our equity securities for a period of 180 days following the date of this prospectus.
Rule 144
In general, under Rule 144, as currently in effect, once we have been subject to public company reporting requirements for at least 90 days, a person (or persons whose shares are aggregated) who is not deemed to be or have been one of our affiliates for purposes of the Securities Act at any time during 90 days preceding a sale and who has beneficially owned the shares proposed to be sold for at least six months, including the holding period of any prior owner other than an affiliate, is entitled to sell such shares without complying with the manner of sale, volume limitation or notice provisions of Rule 144, subject to compliance with the public information requirements of Rule 144. If such a person has beneficially owned the shares proposed to be sold for at least one year, including the holding period of a prior owner other than an affiliate, then such person is entitled to sell such shares without complying with any of the requirements of Rule 144.
In general, under Rule 144, as currently in effect, our affiliates or persons selling shares of our Class A common stock on behalf of our affiliates, who have met the six month holding period for beneficial ownership of “restricted shares” of our Class A common stock, are entitled to sell upon the expiration of the lock-up agreements described above, within any three-month period beginning 90 days after the date of this prospectus, a number of shares that does not exceed the greater of:
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1% of the number of shares of our Class A common stock then outstanding, which will equal approximately shares immediately after this offering; or
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the average reported weekly trading volume of our Class A common stock on Nasdaq during the four calendar weeks preceding the filing of a notice on Form 144 with respect to such sale.
Sales under Rule 144 by our affiliates or persons selling shares on behalf of our affiliates are also subject to certain manner of sale provisions and notice requirements and to the availability of current public information about us. The sale of these shares, or the perception that sales will be made, could adversely affect the price of our Class A common stock after this offering because a great supply of shares would be, or would be perceived to be, available for sale in the public market.
We are unable to estimate the number of shares that will be sold under Rule 144 since this will depend on the market price for our Class A common stock, the personal circumstances of the stockholder and other factors.
Rule 701
In general, under Rule 701 as currently in effect, any of our employees, directors, officers, consultants or advisors who received shares of our Class A common stock from us in connection with a compensatory stock or option plan or other written agreement before the effective date of this offering are entitled to sell such shares 90 days after the effective date of this offering in reliance on Rule 144, in the case of affiliates, without having to comply with the holding period requirements of Rule 144 and, in the case of non-affiliates, without having to comply with the public information, holding period, volume limitation or notice filing requirements of Rule 144.
Registration Statements on Form S-8
We intend to file with the SEC a registration statement on Form S-8 under the Securities Act to register the offer and sale of all shares of Class A common stock reserved for issuance under our 2026 Plan.
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Such registration statement is expected to be filed and become effective as soon as practicable after the completion of this offering. Accordingly, shares registered under such registration statement will be available for sale in the open market following its effective date, subject to certain Rule 144 limitations applicable to affiliates, vesting restrictions, and the lock-up agreements and market standoff restrictions described above, if applicable.
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MATERIAL U.S. FEDERAL INCOME TAX CONSEQUENCES TO NON-U.S. HOLDERS OF THE CLASS A COMMON STOCK
The following discussion is a summary of the material U.S. federal income tax consequences to Non-U.S. Holders (as defined below) of the purchase, ownership, and disposition of our Class A common stock issued pursuant to this offering, but does not purport to be a complete analysis of all potential tax effects. The effects of other U.S. federal tax laws, such as estate and gift tax laws, and any applicable state, local, or non-U.S. tax laws are not discussed. This discussion is based on the Code, Treasury Regulations promulgated thereunder, judicial decisions, and published rulings and administrative pronouncements of the IRS, in each case in effect as of the date hereof. These authorities may change or be subject to differing interpretations. Any such change or differing interpretation may be applied retroactively in a manner that could adversely affect a Non-U.S. Holder. We have not sought and will not seek any rulings from the IRS regarding the matters discussed below. There can be no assurance the IRS or a court will not take a contrary position to that discussed below regarding the tax consequences of the purchase, ownership, and disposition of our Class A common stock.
This discussion is limited to Non-U.S. Holders that hold our Class A common stock as a “capital asset” within the meaning of Section 1221 of the Code (generally, property held for investment). This discussion does not address all U.S. federal income tax consequences relevant to a Non-U.S. Holder’s particular circumstances, including the impact of the Medicare contribution tax on net investment income and the alternative minimum tax. In addition, it does not address consequences relevant to Non-U.S. Holders subject to special rules, including, without limitation:
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U.S. expatriates and former citizens or long-term residents of the U.S.;
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persons holding our Class A common stock as part of a hedge, straddle, or other risk reduction strategy or as part of a conversion transaction or other integrated investment;
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holders of our X-energy Warrants, or any other types of our warrants;
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banks, insurance companies, and other financial institutions;
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brokers, dealers, or traders in securities;
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“controlled foreign corporations,” “foreign controlled foreign corporations,” “passive foreign investment companies,” and corporations that accumulate earnings to avoid U.S. federal income tax;
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partnerships or other entities or arrangements treated as partnerships for U.S. federal income tax purposes (and investors therein);
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tax-exempt organizations or governmental organizations;
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persons deemed to sell our Class A common stock under the constructive sale provisions of the Code;
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persons who hold or receive our Class A common stock pursuant to the exercise of any employee stock option or otherwise as compensation;
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tax-qualified retirement plans;
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“qualified foreign pension funds” as defined in Section 897(l)(2) of the Code and entities all of the interests of which are held by qualified foreign pension funds; and
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persons subject to special tax accounting rules as a result of any item of gross income with respect to the stock being taken into account in an applicable financial statement.
If an entity or arrangement treated as a partnership for U.S. federal income tax purposes holds our Class A common stock, the tax treatment of a partner in the partnership will depend on the status of the partner, the activities of the partnership, and certain determinations made at the partner level. Accordingly, partnerships holding our Class A common stock and the partners in such partnerships should consult their tax advisors regarding the U.S. federal income tax consequences to them.
THIS DISCUSSION IS FOR INFORMATIONAL PURPOSES ONLY AND IS NOT TAX ADVICE. INVESTORS SHOULD CONSULT THEIR TAX ADVISORS WITH RESPECT TO THE APPLICATION OF THE U.S. FEDERAL INCOME TAX LAWS TO THEIR PARTICULAR SITUATIONS AS WELL AS ANY TAX CONSEQUENCES OF THE PURCHASE, OWNERSHIP, AND
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DISPOSITION OF OUR CLASS A COMMON STOCK ARISING UNDER THE U.S. FEDERAL ESTATE OR GIFT TAX LAWS OR UNDER THE LAWS OF ANY STATE, LOCAL, OR NON-U.S. TAXING JURISDICTION OR UNDER ANY APPLICABLE INCOME TAX TREATY.
Definition of a Non-U.S. Holder
For purposes of this discussion, a “Non-U.S. Holder” is any beneficial owner of our Class A common stock that is neither a “U.S. person” nor an entity treated as a partnership for U.S. federal income tax purposes. A U.S. person is any person that, for U.S. federal income tax purposes, is or is treated as any of the following:
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an individual who is a citizen or resident of the U.S.;
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a corporation created or organized under the laws of the U.S., any state thereof, or the District of Columbia;
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an estate, the income of which is subject to U.S. federal income tax regardless of its source; or
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a trust that (1) is subject to the primary supervision of a U.S. court and the control of one or more “United States persons” (within the meaning of Section 7701(a)(30) of the Code), or (2) has a valid election in effect to be treated as a U.S. person for U.S. federal income tax purposes.
Distributions
As described in the section entitled “Dividend Policy,” we do not anticipate declaring or paying dividends to holders of our Class A common stock in the foreseeable future. However, if we do make distributions of cash or property on our Class A common stock, such distributions will constitute dividends for U.S. federal income tax purposes to the extent paid from our current or accumulated earnings and profits, as determined under U.S. federal income tax principles. Amounts not treated as dividends for U.S. federal income tax purposes will constitute a return of capital and first be applied against and reduce a Non-U.S. Holder’s adjusted tax basis in its Class A common stock, but not below zero. Any excess will be treated as capital gain and will be treated as described below under “— Sale or Other Taxable Disposition.”
Subject to the discussion below on effectively connected income, dividends paid to a Non-U.S. Holder will be subject to U.S. federal withholding tax at a rate of 30% of the gross amount of the dividends (or such lower rate specified by an applicable income tax treaty, provided the Non-U.S. Holder furnishes a valid IRS Form W-8BEN or W-8BEN-E (or other applicable documentation) certifying qualification for the lower treaty rate). A Non-U.S. Holder that does not timely furnish the required documentation, but that qualifies for a reduced treaty rate, may obtain a refund of any excess amounts withheld by timely filing an appropriate claim for refund with the IRS. Non-U.S. Holders should consult their tax advisors regarding their entitlement to benefits under any applicable income tax treaty.
If dividends paid to a Non-U.S. Holder are effectively connected with the Non-U.S. Holder’s conduct of a trade or business within the U.S. (and, if required by an applicable income tax treaty, the Non-U.S. Holder maintains a permanent establishment in the U.S. to which such dividends are attributable), the Non-U.S. Holder will be exempt from the U.S. federal withholding tax described above. To claim the exemption, the Non-U.S. Holder must furnish to the applicable withholding agent a valid IRS Form W-8ECI, certifying that the dividends are effectively connected with the Non-U.S. Holder’s conduct of a trade or business within the U.S.
Any such effectively connected dividends will be subject to U.S. federal income tax on a net income basis at the regular rates. A Non-U.S. Holder that is a corporation also may be subject to a branch profits tax at a rate of 30% (or such lower rate specified by an applicable income tax treaty) on such effectively connected dividends, as adjusted for certain items. Non-U.S. Holders should consult their tax advisors regarding any applicable tax treaties that may provide for different rules.
Sale or Other Taxable Disposition
A Non-U.S. Holder will not be subject to U.S. federal income tax on any gain realized upon the sale or other taxable disposition of our Class A common stock unless:
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the gain is effectively connected with the Non-U.S. Holder’s conduct of a trade or business within the U.S. (and, if required by an applicable income tax treaty, the Non-U.S. Holder maintains a permanent establishment in the U.S. to which such gain is attributable);
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the Non-U.S. Holder is a nonresident alien individual present in the U.S. for 183 days or more during the taxable year of the disposition and certain other requirements are met; or
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our Class A common stock constitutes a U.S. real property interest (“USRPI”) by reason of our status as a U.S. real property holding corporation (“USRPHC”) for U.S. federal income tax purposes.
Gain described in the first bullet point above generally will be subject to U.S. federal income tax on a net income basis at the regular rates. A Non-U.S. Holder that is a corporation also may be subject to a branch profits tax at a rate of 30% (or such lower rate specified by an applicable income tax treaty) on such effectively connected gain, as adjusted for certain items.
A Non-U.S. Holder described in the second bullet point above will be subject to U.S. federal income tax at a rate of 30% (or such lower rate specified by an applicable income tax treaty) on gain realized upon the sale or other taxable disposition of our Class A common stock, which may be offset by U.S. source capital losses of the Non-U.S. Holder (even though the individual is not considered a resident of the U.S.), provided the Non-U.S. Holder has timely filed U.S. federal income tax returns with respect to such losses.
With respect to the third bullet point above, we believe we currently are not, and do not anticipate becoming, a USRPHC. Because the determination of whether we are a USRPHC depends, however, on the fair market value of our USRPIs relative to the fair market value of our non-U.S. real property interests and our other business assets, there can be no assurance we currently are not a USRPHC or will not become one in the future. Even if we are or were to become a USRPHC, gain arising from the sale or other taxable disposition of our Class A common stock by a Non-U.S. Holder will not be subject to U.S. federal income tax if our Class A common stock is “regularly traded,” as defined by applicable Treasury Regulations, on an established securities market and such Non-U.S. Holder owned, actually and constructively, 5% or less of our Class A common stock throughout the shorter of the five-year period ending on the date of the sale or other taxable disposition or the Non-U.S. Holder’s holding period.
Non-U.S. Holders should consult their tax advisors regarding potentially applicable income tax treaties that may provide for different rules.
Information Reporting and Backup Withholding
Payments of dividends on our Class A common stock will not be subject to backup withholding, provided the applicable withholding agent does not have actual knowledge or reason to know the holder is a U.S. person and the holder either certifies its non-U.S. status, such as by furnishing a valid IRS Form W-8BEN, W-8BEN-E, or W-8ECI, or otherwise establishes an exemption. However, information returns are required to be filed with the IRS in connection with any distributions on our Class A common stock paid to the Non-U.S. Holder, regardless of whether such distributions constitute dividends or whether any tax was actually withheld. In addition, proceeds of the sale or other taxable disposition of our Class A common stock within the U.S. or conducted through certain U.S.-related brokers generally will not be subject to backup withholding or information reporting if the applicable withholding agent receives the certification described above and does not have actual knowledge or reason to know that such holder is a U.S. person or the holder otherwise establishes an exemption. Proceeds of a disposition of our Class A common stock conducted through a non-U.S. office of a non-U.S. broker generally will not be subject to backup withholding or information reporting.
Copies of information returns that are filed with the IRS may also be made available under the provisions of an applicable treaty or agreement to the tax authorities of the country in which the Non-U.S. Holder resides or is established.
Backup withholding is not an additional tax. Any amounts withheld under the backup withholding rules may be allowed as a refund or a credit against a Non-U.S. Holder’s U.S. federal income tax liability, provided the required information is timely furnished to the IRS.
Additional Withholding Tax on Payments Made to Foreign Accounts
Withholding taxes may be imposed under Sections 1471 to 1474 of the Code (such Sections commonly referred to as the Foreign Account Tax Compliance Act, or “FATCA”) on certain types of payments made to
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non-U.S. financial institutions and certain other non-U.S. entities. Specifically, a 30% withholding tax may be imposed on dividends on, or (subject to the proposed Treasury Regulations discussed below) gross proceeds from the sale or other disposition of, our Class A common stock paid to a “foreign financial institution” or a “non-financial foreign entity” (each as defined in the Code), unless (1) the foreign financial institution undertakes certain diligence and reporting obligations, (2) the non-financial foreign entity either certifies it does not have any “substantial United States owners” (as defined in the Code) or furnishes identifying information regarding each substantial U.S. owner, or (3) the foreign financial institution or non-financial foreign entity otherwise qualifies for an exemption from these rules. If the payee is a foreign financial institution and is subject to the diligence and reporting requirements in (1) above, it must enter into an agreement with the U.S. Department of the Treasury requiring, among other things, that it undertake to identify accounts held by certain “specified United States persons” or “United States owned foreign entities” (each as defined in the Code), annually report certain information about such accounts, and withhold 30% on certain payments to non-compliant foreign financial institutions and certain other account holders. Foreign financial institutions located in jurisdictions that have an intergovernmental agreement with the U.S. governing FATCA may be subject to different rules.
Under the applicable Treasury Regulations and administrative guidance, withholding under FATCA generally applies to payments of dividends on our Class A common stock. While withholding under FATCA would have applied also to payments of gross proceeds from the sale or other disposition of stock on or after January 1, 2019, proposed Treasury Regulations eliminate FATCA withholding on payments of gross proceeds entirely. Taxpayers generally may rely on these proposed Treasury Regulations until final Treasury Regulations are issued.
Prospective investors should consult their tax advisors regarding the potential application of withholding under FATCA to their investment in our Class A common stock.
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UNDERWRITING
We, the selling shareholders, and the underwriters named below have entered into an underwriting agreement with respect to the shares of Class A common stock described in this prospectus. J.P. Morgan Securities LLC and are acting as the representatives of the underwriters. Subject to the terms and conditions of the underwriting agreement, each underwriter has severally agreed to purchase, at the public offering price less the underwriting discounts and commissions set forth on the cover page of this prospectus, the number of shares of Class A common stock indicated in the following table.
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Name
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Number of Shares
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|
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J.P. Morgan Securities LLC
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| |
|
|
| | | | | |
| Total | | | | |
The underwriters are committed to purchase all the shares of Class A common stock offered by us and the selling shareholders if they purchase any shares of Class A common stock. The underwriting agreement also provides that if an underwriter defaults, the purchase commitments of non-defaulting underwriters may also be increased or the offering may be terminated.
Shares of Class A common stock sold by the underwriters to the public will initially be offered at the initial public offering price set forth on the cover of this prospectus. Any shares of Class A common stock sold by the underwriters to securities dealers may be sold at a discount of up to $ per share of Class A common stock from the initial public offering price. After the initial offering of the shares of Class A common stock, the representatives may change the offering price and the other selling terms. The offering of the shares of Class A common stock by the underwriters is subject to receipt and acceptance and subject to the underwriters’ right to reject any order in whole or in part. Sales of any shares of Class A common stock made outside of the U.S. may be made by affiliates of the underwriters.
To the extent that the underwriters sell more than shares of Class A common stock in this offering, the underwriters have the option to purchase, exercisable within 30 days from the date of this prospectus, up to an additional shares of Class A common stock from us and up to an additional shares of Class A common stock from the selling shareholders, in each case, at the public offering price less the underwriting discounts and commissions. If any shares of Class A common stock are purchased with this option to purchase additional shares of Class A common stock, the underwriters will severally purchase shares of Class A common stock in approximately the same proportion as shown in the table above. If any additional shares of Class A common stock are purchased, the underwriters will offer the additional shares on the same terms as those on which the shares are being offered.
The underwriting fee is equal to the public offering price per share less the amount paid by the underwriters to us and the selling shareholders per share. The following table shows the per-share and total underwriting discounts and commissions to be paid to the underwriters assuming both no exercise and full exercise of the underwriters’ option to purchase additional shares of Class A common stock.
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Issuer
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Selling Shareholders
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Without option
to purchase additional shares exercise |
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With full option
to purchase additional shares exercise |
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Without option
to purchase additional shares exercise |
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With full option
to purchase additional shares exercise |
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Per Share
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We estimate that the total expenses of this offering, including registration, filing and listing fees, printing fees and legal and accounting expenses, but excluding the underwriting discounts and commissions, will be approximately $ .
A prospectus in electronic format may be made available on the web sites maintained by one or more underwriters, or selling group members, if any, participating in the offering. The underwriters may agree to allocate a number of shares of Class A common stock to underwriters and selling group members for sale to
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their online brokerage account holders. Internet distributions will be allocated by the representatives to underwriters and selling group members that may make Internet distributions on the same basis as other allocations.
We have agreed that we will not (i) offer, pledge, sell, contract to sell, sell any option or contract to purchase, purchase any option or contract to sell, grant any option, right or warrant to purchase, lend or otherwise transfer or dispose of, directly or indirectly, or submit to, or file with, the Securities and Exchange Commission a registration statement under the Securities Act relating to, any shares of our common stock or securities convertible into or exercisable or exchangeable for any shares of our common stock, or publicly disclose the intention to make any offer, sale, pledge, loan, disposition or filing, or (ii) enter into any swap or other arrangement that transfers all or a portion of the economic consequences associated with the ownership of any shares of common stock or any such other securities (regardless of whether any of these transactions are to be settled by the delivery of shares of common stock or such other securities, in cash or otherwise), in each case without the prior written consent of J.P. Morgan Securities LLC and for a period of days after the date of this prospectus, other than the shares of our common stock to be sold in this offering.
The restrictions on our actions, as described above, do not apply to certain transactions, including (i) the issuance of shares of common stock or securities convertible into or exercisable for shares of our common stock pursuant to the conversion or exchange of convertible or exchangeable securities or the exercise of warrants or options (including net exercise) or the settlement of restricted stock units (“RSUs”) (including net settlement), in each case outstanding on the date of the underwriting agreement and described in this prospectus; (ii) grants of stock options, stock awards, restricted stock, RSUs, or other equity awards and the issuance of shares of our common stock or securities convertible into or exercisable or exchangeable for shares of our common stock (whether upon the exercise of stock options or otherwise) to our employees, officers, directors, advisors, or consultants pursuant to the terms of an equity compensation plan in effect as of the closing of this offering and described in this prospectus, provided that such recipients enter into a lock-up agreement with the underwriters; or (iii) our filing of any registration statement on Form S-8 relating to securities granted or to be granted pursuant to any plan in effect on the date of the underwriting agreement and described in this prospectus or any assumed benefit plan pursuant to an acquisition or similar strategic transaction.
Our directors, officers, and the selling shareholders (such persons, the “lock-up parties”) have entered into lock-up agreements with the underwriters prior to the commencement of this offering pursuant to which each lock-up party, with limited exceptions, for a period of days after the date of this prospectus (such period, the “restricted period”), may not (and may not cause any of their direct or indirect affiliates to), without the prior written consent of J.P. Morgan Securities LLC and , (1) offer, pledge, sell, contract to sell, sell any option or contract to purchase, purchase any option or contract to sell, grant any option, right or warrant to purchase, lend or otherwise transfer or dispose of, directly or indirectly, any shares of our common stock or any securities convertible into or exercisable or exchangeable for our common stock (including, without limitation, common stock or such other securities which may be deemed to be beneficially owned by such lock-up parties in accordance with the rules and regulations of the SEC and securities which may be issued upon exercise of a stock option or warrant (collectively with the common stock, the “lock-up securities”)), (2) enter into any hedging, swap or other agreement or transaction that transfers, in whole or in part, any of the economic consequences of ownership of the lock-up securities, whether any such transaction described in clause (1) or (2) above is to be settled by delivery of lock-up securities, in cash or otherwise, (3) make any demand for, or exercise any right with respect to, the registration of any lock-up securities, or (4) publicly disclose the intention to do any of the foregoing. Such persons or entities have further acknowledged that these undertakings preclude them from engaging in any hedging or other transactions or arrangements (including, without limitation, any short sale or the purchase or sale of, or entry into, any put or call option, or combination thereof, forward, swap or any other derivative transaction or instrument, however described or defined) designed or intended, or which could reasonably be expected to lead to or result in, a sale or disposition or transfer (by any person or entity, whether or not a signatory to such agreement) of any economic consequences of ownership, in whole or in part, directly or indirectly, of any lock-up securities, whether any such transaction or arrangement (or instrument provided for thereunder) would be settled by delivery of lock-up securities, in cash or otherwise.
The restrictions described in the immediately preceding paragraph and contained in the lock-up agreements between the underwriters and the lock-up parties do not apply, subject in certain cases to various
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conditions, to certain transactions, including (a) transfers of lock-up securities: (i) as bona fide gifts, or for bona fide estate planning purposes, (ii) by will or intestacy, (iii) to any trust for the direct or indirect benefit of the lock-up party or any immediate family member, (iv) to a partnership, limited liability company or other entity of which the lock-up party and its immediate family members are the legal and beneficial owner of all of the outstanding equity securities or similar interests, (v) to a nominee or custodian of a person or entity to whom a disposition or transfer would be permissible under clauses (i) through (iv), (vi) in the case of a corporation, partnership, limited liability company, trust or other business entity, (A) to another corporation, partnership, limited liability company, trust or other business entity that is an affiliate of the lock-up party, or to any investment fund or other entity controlling, controlled by, managing or managed by or under common control with the lock-up party or its affiliates or (B) as part of a distribution to members or shareholders of the lock-up party; (vii) by operation of law, (viii) to us from an employee upon death, disability or termination of employment of such employee, (ix) as part of a sale of lock-up securities acquired in open market transactions after the completion of this offering, (x) to us in connection with the vesting, settlement or exercise of restricted stock units, options, warrants or other rights to purchase shares of our common stock (including “net” or “cashless” exercise), including for the payment of exercise price and tax and remittance payments, or (xi) pursuant to a bona fide third-party tender offer, merger, consolidation or other similar transaction approved by our board of directors and made to all shareholders involving a change in control, provided that if such transaction is not completed, all such lock-up securities would remain subject to the restrictions in the immediately preceding paragraph; (b) exercise of the options, settlement of RSUs or other equity awards, or the exercise of warrants granted pursuant to plans described in this prospectus, provided that any lock-up securities received upon such exercise, vesting or settlement would be subject to restrictions similar to those in the immediately preceding paragraph; (c) the conversion of outstanding preferred stock, warrants to acquire preferred stock, or convertible securities into shares of our common stock or warrants to acquire shares of our common stock, provided that any common stock or warrant received upon such conversion would be subject to restrictions similar to those in the immediately preceding paragraph; and (d) the establishment by lock-up parties of trading plans under Rule 10b5-1 under the Exchange Act, provided that such plan does not provide for the transfer of lock-up securities during the restricted period; and (e) the sale of our common stock to the selling shareholders pursuant to the terms of the underwriting agreement.
J.P. Morgan Securities LLC and , in their sole discretion, may release the securities subject to any of the lock-up agreements with the underwriters described above, in whole or in part at any time.
We, and the selling shareholders, have agreed to indemnify the underwriters against certain liabilities, including liabilities under the Securities Act of 1933.
We intend to apply to list our Class A common stock on Nasdaq under the symbol “XE.”
In connection with this offering, the underwriters may engage in stabilizing transactions, which involves making bids for, purchasing and selling shares of Class A common stock in the open market for the purpose of preventing or retarding a decline in the market price of the Class A common stock while this offering is in progress. These stabilizing transactions may include making short sales of Class A common stock, which involves the sale by the underwriters of a greater number of shares of Class A common stock than they are required to purchase in this offering, and purchasing shares of Class A common stock on the open market to cover positions created by short sales. Short sales may be “covered” shorts, which are short positions in an amount not greater than the underwriters’ option to purchase additional shares of Class A common stock referred to above, or may be “naked” shorts, which are short positions in excess of that amount. The underwriters may close out any covered short position either by exercising their option to purchase additional shares of Class A common stock, in whole or in part, or by purchasing shares of Class A common stock in the open market. In making this determination, the underwriters will consider, among other things, the price of shares of Class A common stock available for purchase in the open market compared to the price at which the underwriters may purchase shares of Class A common stock through the option to purchase additional shares of Class A common stock. A naked short position is more likely to be created if the underwriters are concerned that there may be downward pressure on the price of the Class A common stock in the open market that could adversely affect investors who purchase in this offering. To the extent that the underwriters create a naked short position, they will purchase shares of Class A common stock in the open market to cover the position.
The underwriters have advised us that, pursuant to Regulation M of the Securities Act of 1933, they may also engage in other activities that stabilize, maintain or otherwise affect the price of the Class A common
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stock, including the imposition of penalty bids. This means that if the representatives of the underwriters purchase Class A common stock in the open market in stabilizing transactions or to cover short sales, the representatives can require the underwriters that sold those shares of Class A common stock as part of this offering to repay the underwriting discount received by them.
These activities may have the effect of raising or maintaining the market price of the Class A common stock or preventing or retarding a decline in the market price of the Class A common stock, and, as a result, the price of the Class A common stock may be higher than the price that otherwise might exist in the open market. If the underwriters commence these activities, they may discontinue them at any time. The underwriters may carry out these transactions on Nasdaq, in the over the counter market or otherwise.
Prior to this offering, there has been no public market for our Class A common stock. The initial public offering price will be determined by negotiations between us, the selling shareholders and the representatives. In determining the initial public offering price, we, the selling shareholders and the representatives of the underwriters expect to consider a number of factors including:
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the information set forth in this prospectus and otherwise available to the representatives;
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our prospects and the history and prospects for the industry in which we compete;
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an assessment of our management;
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our prospects for future earnings;
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the general condition of the securities markets at the time of this offering;
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the recent market prices of, and demand for, publicly traded common stock of generally comparable companies; and
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other factors deemed relevant by the underwriters and us.
Neither we, the selling shareholders nor the underwriters can assure investors that an active trading market will develop for our shares of Class A common stock, or that the shares of Class A common stock will trade in the public market at or above the initial public offering price.
The underwriters and their respective affiliates are full service financial institutions engaged in various activities, which may include sales and trading, commercial and investment banking, advisory, investment management, investment research, principal investment, hedging, market making, brokerage and other financial and non-financial activities and services. Certain of the underwriters and their respective affiliates have provided, and may in the future provide, a variety of these services to the issuer and to persons and entities with relationships with the issuer, for which they received or will receive customary fees and expenses. In addition, from time to time, certain of the underwriters and their affiliates may effect transactions for their own account or the account of customers, and hold on behalf of themselves or their customers, long or short positions in our debt or equity securities or loans, and may do so in the future.
Other than in the U.S., no action has been taken by us, the selling shareholders or the underwriters that would permit a public offering of the securities offered by this prospectus in any jurisdiction where action for that purpose is required. The securities offered by this prospectus may not be offered or sold, directly or indirectly, nor may this prospectus or any other offering material or advertisements in connection with the offer and sale of any such securities be distributed or published in any jurisdiction, except under circumstances that will result in compliance with the applicable rules and regulations of that jurisdiction. Persons into whose possession this prospectus comes are advised to inform themselves about and to observe any restrictions relating to the offering and the distribution of this prospectus. This prospectus does not constitute an offer to sell or a solicitation of an offer to buy any securities offered by this prospectus in any jurisdiction in which such an offer or a solicitation is unlawful.
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NOTICE TO PROSPECTIVE INVESTORS IN THE EUROPEAN ECONOMIC AREA
In relation to each Member State of the European Economic Area (each a “Relevant State”), no shares have been offered or will be offered pursuant to the offering to the public in that Relevant State prior to the publication of a prospectus in relation to the shares which has been approved by the competent authority in that Relevant State or, where appropriate, approved in another Relevant State and notified to the competent authority in that Relevant State, all in accordance with the Prospectus Regulation, except that offers of shares may be made to the public in that Relevant State at any time under the following exemptions under the Prospectus Regulation:
(a) to any legal entity which is a qualified investor as defined under Article 2 of the Prospectus Regulation;
(b) to fewer than 150 natural or legal persons (other than qualified investors as defined under Article 2 of the Prospectus Regulation), subject to obtaining the prior consent of the underwriters; or
(c) in any other circumstances falling within Article 1(4) of the Prospectus Regulation,
provided that no such offer of shares shall require us, the selling shareholders or any underwriter to publish a prospectus pursuant to Article 3 of the Prospectus Regulation or supplement a prospectus pursuant to Article 23 of the Prospectus Regulation, and each person who initially acquires any shares or to whom any offer is made will be deemed to have represented, acknowledged and agreed to and with each of the underwriters and the Company that it is a “qualified investor” within the meaning of Article 2(e) of the Prospectus Regulation. In the case of any shares being offered to a financial intermediary as that term is used in the Prospectus Regulation, each such financial intermediary will be deemed to have represented, acknowledged and agreed that the shares acquired by it in the offer have not been acquired on a non-discretionary basis on behalf of, nor have they been acquired with a view to their offer or resale to, persons in circumstances which may give rise to an offer of any shares to the public other than their offer or resale in a Relevant State to qualified investors as so defined or in circumstances in which the prior consent of the underwriters have been obtained to each such proposed offer or resale.
For the purposes of this provision, the expression an “offer to the public” in relation to shares in any Relevant State means the communication in any form and by any means of sufficient information on the terms of the offer and any shares to be offered so as to enable an investor to decide to purchase or subscribe for any shares, and the expression “Prospectus Regulation” means Regulation (EU) 2017/1129.
NOTICE TO PROSPECTIVE INVESTORS IN THE UNITED KINGDOM
No shares have been offered or will be offered pursuant to the offering to the public in the U.K. prior to the publication of a prospectus in relation to the shares which has been approved by the Financial Conduct Authority, except that the shares may be offered to the public in the U.K. at any time:
(a) to any legal entity which is a qualified investor as defined under Article 2 of the U.K. Prospectus Regulation;
(b) to fewer than 150 natural or legal persons (other than qualified investors as defined under Article 2 of the U.K. Prospectus Regulation), subject to obtaining the prior consent of underwriters for any such offer; or
(c) in any other circumstances falling within Section 86 of the Financial Services and Markets Act 2000 (“FSMA”);
provided that no such offer of the shares shall require the Company or any underwriter to publish a prospectus pursuant to Section 85 of the FSMA or supplement a prospectus pursuant to Article 23 of the U.K. Prospectus Regulation. For the purposes of this provision, the expression an “offer to the public” in relation to the shares in the U.K. means the communication in any form and by any means of sufficient information on the terms of the offer and any shares to be offered so as to enable an investor to decide to purchase or subscribe for any shares and the expression “U.K. Prospectus Regulation” means Regulation (EU) 2017/1129 as it forms part of domestic law by virtue of the European Union (Withdrawal) Act 2018.
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In addition, in the U.K., this document is being distributed only to, and is directed only at, and any offer subsequently made may only be directed at persons who are “qualified investors” (as defined in the Prospectus Regulation) (i) who have professional experience in matters relating to investments falling within Article 19(5) of the Financial Services and Markets Act 2000 (Financial Promotion) Order 2005, as amended (the “Order”) and/or (ii) who are high net worth companies (or persons to whom it may otherwise be lawfully communicated) falling within Article 49(2)(a) to (d) of the Order (all such persons together being referred to as “relevant persons”) or otherwise in circumstances which have not resulted and will not result in an offer to the public of the shares in the U.K. within the meaning of the FSMA.
Any person in the U.K. that is not a relevant person should not act or rely on the information included in this document or use it as basis for taking any action. In the U.K., any investment or investment activity that this document relates to may be made or taken exclusively by relevant persons.
NOTICE TO PROSPECTIVE INVESTORS IN CANADA
The shares may be sold only to purchasers purchasing, or deemed to be purchasing, as principal that are accredited investors, as defined in National Instrument 45-106 Prospectus Exemptions or subsection 73.3(1) of the Securities Act (Ontario), and are permitted clients, as defined in National Instrument 31-103 Registration Requirements, Exemptions and Ongoing Registrant Obligations. Any resale of the shares must be made in accordance with an exemption from, or in a transaction not subject to, the prospectus requirements of applicable securities laws.
Securities legislation in certain provinces or territories of Canada may provide a purchaser with remedies for rescission or damages if this prospectus (including any amendment thereto) contains a misrepresentation, provided that the remedies for rescission or damages are exercised by the purchaser within the time limit prescribed by the securities legislation of the purchaser’s province or territory. The purchaser should refer to any applicable provisions of the securities legislation of the purchaser’s province or territory for particulars of these rights or consult with a legal advisor.
Pursuant to section 3A.3 of National Instrument 33-105 Underwriting Conflicts (NI 33-105), the underwriters are not required to comply with the disclosure requirements of NI 33-105 regarding underwriter conflicts of interest in connection with this offering.
NOTICE TO PROSPECTIVE INVESTORS IN SWITZERLAND
This prospectus does not constitute an offer to the public or a solicitation to purchase or invest in any shares. No shares have been offered or will be offered to the public in Switzerland, except that offers of shares may be made to the public in Switzerland at any time under the following exemptions under the Swiss Financial Services Act (“FinSA”):
(a) to any person which is a professional client as defined under the FinSA;
(b) to fewer than 500 persons (other than professional clients as defined under the FinSA), subject to obtaining the prior consent of J.P. Morgan Securities LLC and for any such offer; or
(c) in any other circumstances falling within Article 36 FinSA in connection with Article 44 of the Swiss Financial Services Ordinance,
provided that no such offer of shares shall require the Company or any investment bank to publish a prospectus pursuant to Article 35 FinSA.
The shares have not been and will not be listed or admitted to trading on a trading venue in Switzerland.
Neither this document nor any other offering or marketing material relating to the shares constitutes a prospectus as such term is understood pursuant to the FinSA and neither this document nor any other offering or marketing material relating to the shares may be publicly distributed or otherwise made publicly available in Switzerland.
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NOTICE TO PROSPECTIVE INVESTORS IN THE DUBAI INTERNATIONAL FINANCIAL CENTRE (“DIFC”)
This document relates to an Exempt Offer in accordance with the Markets Law, DIFC Law No. 1 of 2012, as amended. This document is intended for distribution only to persons of a type specified in the Markets Law, DIFC Law No. 1 of 2012, as amended. It must not be delivered to, or relied on by, any other person. The Dubai Financial Services Authority (DFSA) has no responsibility for reviewing or verifying any documents in connection with Exempt Offers. The DFSA has not approved this prospectus supplement nor taken steps to verify the information set forth herein and has no responsibility for this document. The securities to which this document relates may be illiquid and/or subject to restrictions on their resale. Prospective purchasers of the securities offered should conduct their own due diligence on the securities. If you do not understand the contents of this document you should consult an authorized financial advisor.
In relation to its use in the DIFC, this document is strictly private and confidential and is being distributed to a limited number of investors and must not be provided to any person other than the original recipient, and may not be reproduced or used for any other purpose. The interests in the securities may not be offered or sold directly or indirectly to the public in the DIFC.
NOTICE TO PROSPECTIVE INVESTORS IN THE UNITED ARAB EMIRATES
The shares have not been, and are not being, publicly offered, sold, promoted or advertised in the United Arab Emirates (including the Dubai International Financial Centre) other than in compliance with the laws of the United Arab Emirates (and the Dubai International Financial Centre) governing the issue, offering and sale of securities. Further, this prospectus does not constitute a public offer of securities in the United Arab Emirates (including the Dubai International Financial Centre) and is not intended to be a public offer. This prospectus has not been approved by or filed with the Central Bank of the United Arab Emirates, the Securities and Commodities Authority, Financial Services Regulatory Authority (FSRA) or the Dubai Financial Services Authority (DFSA).
NOTICE TO PROSPECTIVE INVESTORS IN AUSTRALIA
This prospectus:
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does not constitute a disclosure document or a prospectus under Chapter 6D.2 of the Corporations Act 2001 (Cth) (the “Corporations Act”);
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has not been, and will not be, lodged with the Australian Securities and Investments Commission (“ASIC”), as a disclosure document for the purposes of the Corporations Act and does not purport to include the information required of a disclosure document for the purposes of the Corporations Act; and
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may only be provided in Australia to select investors who are able to demonstrate that they fall within one or more of the categories of investors, available under section 708 of the Corporations Act (“Exempt Investors”).
The shares may not be directly or indirectly offered for subscription or purchased or sold, and no invitations to subscribe for or buy the shares may be issued, and no draft or definitive offering memorandum, advertisement or other offering material relating to any shares may be distributed in Australia, except where disclosure to investors is not required under Chapter 6D of the Corporations Act or is otherwise in compliance with all applicable Australian laws and regulations. By submitting an application for the shares, you represent and warrant to us and the selling shareholders that you are an Exempt Investor.
As any offer of shares under this document will be made without disclosure in Australia under Chapter 6D.2 of the Corporations Act, the offer of those securities for resale in Australia within 12 months may, under section 707 of the Corporations Act, require disclosure to investors under Chapter 6D.2 if none of the exemptions in section 708 applies to that resale. By applying for the shares, you undertake to us and the selling shareholders that you will not, for a period of 12 months from the date of issue of the shares, offer, transfer, assign or otherwise alienate those shares to investors in Australia except in circumstances where disclosure to investors is not required under Chapter 6D.2 of the Corporations Act or where a compliant disclosure document is prepared and lodged with ASIC.
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NOTICE TO PROSPECTIVE INVESTORS IN JAPAN
The shares have not been and will not be registered pursuant to Article 4, Paragraph 1 of the Financial Instruments and Exchange Act. Accordingly, none of the shares nor any interest therein may be offered or sold, directly or indirectly, in Japan or to, or for the benefit of, any “resident” of Japan (which term as used herein means any person resident in Japan, including any corporation or other entity organized under the laws of Japan), or to others for re-offering or resale, directly or indirectly, in Japan or to or for the benefit of a resident of Japan, except pursuant to an exemption from the registration requirements of, and otherwise in compliance with, the Financial Instruments and Exchange Act and any other applicable laws, regulations and ministerial guidelines of Japan in effect at the relevant time.
NOTICE TO PROSPECTIVE INVESTORS IN HONG KONG
The shares have not been offered or sold and will not be offered or sold in Hong Kong, by means of any document, other than (a) to “professional investors” as defined in the Securities and Futures Ordinance (Cap. 571 of the Laws of Hong Kong) (the “SFO”) of Hong Kong and any rules made thereunder; or (b) in other circumstances which do not result in the document being a “prospectus” as defined in the Companies (Winding Up and Miscellaneous Provisions) Ordinance (Cap. 32) of Hong Kong (the “CO”) or which do not constitute an offer to the public within the meaning of the CO. No advertisement, invitation or document relating to the shares has been or may be issued or has been or may be in the possession of any person for the purposes of issue, whether in Hong Kong or elsewhere, which is directed at, or the contents of which are likely to be accessed or read by, the public of Hong Kong (except if permitted to do so under the securities laws of Hong Kong) other than with respect to shares which are or are intended to be disposed of only to persons outside Hong Kong or only to “professional investors” as defined in the SFO and any rules made thereunder.
NOTICE TO PROSPECTIVE INVESTORS IN SINGAPORE
Each of J.P. Morgan Securities LLC, and the Company has acknowledged that this prospectus has not been registered as a prospectus with the Monetary Authority of Singapore. Accordingly, each of J.P. Morgan Securities LLC, and the Company has represented and agreed that it has not offered or sold any shares or caused the shares to be made the subject of an invitation for subscription or purchase and will not offer or sell any shares or cause the shares to be made the subject of an invitation for subscription or purchase, and has not circulated or distributed, nor will it circulate or distribute, this prospectus or any other document or material in connection with the offer or sale, or invitation for subscription or purchase, of the shares, whether directly or indirectly, to any person in Singapore other than:
(a) to an institutional investor (as defined in Section 4A of the Securities and Futures Act (Chapter 289) of Singapore, as modified or amended from time to time (the “SFA”)) pursuant to Section 274 of the SFA;
(b) to a relevant person (as defined in Section 275(2) of the SFA) pursuant to Section 275(1) of the SFA, or any person pursuant to Section 275(1A) of the SFA, and in accordance with the conditions specified in Section 275 of the SFA; or
(c) otherwise, pursuant to, and in accordance with the conditions of, any other applicable provision of the SFA.
Where the shares are subscribed or purchased under Section 275 of the SFA by a relevant person which is:
(a) a corporation (which is not an accredited investor (as defined in Section 4A of the SFA)) the sole business of which is to hold investments and the entire share capital of which is owned by one or more individuals, each of whom is an accredited investor; or
(b) a trust (where the trustee is not an accredited investor) whose sole purpose is to hold investments and each beneficiary of the trust is an individual who is an accredited investor,
securities or securities-based derivatives contracts (each term as defined in Section 2(1) of the SFA) of that corporation or the beneficiaries’ rights and interest (howsoever described) in that trust shall not be transferred within six months after that corporation or that trust has acquired the shares pursuant to an offer made under Section 275 of the SFA except:
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(i) to an institutional investor or to a relevant person, or to any person arising from an offer referred to in Section 275(1A) or Section 276(4)(c)(ii) of the SFA;
(ii) where no consideration is or will be given for the transfer;
(iii) where the transfer is by operation of law;
(iv) as specified in Section 276(7) of the SFA; or
(v) as specified in Regulation 37A of the Securities and Futures (Offers of Investments) (Securities and Securities-based Derivatives Contracts) Regulations 2018.
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LEGAL MATTERS
Latham & Watkins LLP, New York, New York, which has acted as our counsel in connection with this offering, will pass upon the validity of the issuance of the shares of our Class A common stock offered by this prospectus. Certain legal matters in connection with this offering will be passed upon for the underwriters by Skadden, Arps, Slate, Meagher & Flom LLP.
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EXPERTS
The consolidated financial statements of X-Energy Reactor Company, LLC at December 31, 2024, and for the year ended December 31, 2024, appearing in this Prospectus and Registration Statement have been audited by Ernst & Young LLP, independent registered public accounting firm, and at December 31, 2023, and for the year then ended, by Grant Thornton LLP, independent registered public accounting firm, as set forth in their respective reports thereon appearing elsewhere herein, and are included in reliance upon such reports given on the authority of such firms as experts in accounting and auditing.
CHANGE IN AUDITOR
On May 2, 2025, the Company notified Grant Thornton LLP (“GT”) of its intent to change the Company’s certifying accountant. On June 9, 2025, the Company appointed Ernst & Young LLP (“EY”) as its new independent registered public accounting firm. The reports of GT on the Company’s consolidated financial statements for the fiscal years ended December 31, 2024 and 2023 did not contain an adverse opinion or a disclaimer of opinion, and were not qualified or modified as to uncertainty, audit scope or accounting principles. During the years ended December 31, 2024 and 2023, and the subsequent interim period through May 2, 2025, there were (i) no disagreements between the Company and GT on any matter of accounting principles or practices, financial statement disclosure or auditing scope or procedure, which, if not resolved to GT’s satisfaction, would have caused GT to make reference to the subject matter of the disagreement in connection with its report for such years, and (ii) no “reportable events” as defined in Item 304(a)(1)(v) of Regulation S-K for such years and subsequent interim period through May 2, 2025, except for GT’s communication of the material weakness discussed in the Risk Factors section. The Company discussed such reportable events with GT, and the Company has authorized GT to respond fully to the inquiries of EY concerning such reportable events. In connection with the filing of this Registration Statement, EY reaudited the Company’s financial statements for the year ended December 31, 2024 under the standards of the Public Company Accounting Oversight Board (United States) (“PCAOB”), and EY’s report for the fiscal year ended December 31, 2024 is included herein. Accordingly, GT’s previously issued report on the fiscal year ended December 31, 2024 is not included in this Registration Statement. During the years ended December 31, 2024 and 2023, and the subsequent interim period through May 2, 2025, neither the Company nor anyone on its behalf has consulted EY with respect to either (i) the application of accounting principles to a specified transaction, either completed or proposed, or the type of audit opinion that might be rendered on the Company’s consolidated financial statements or the effectiveness of internal control over financial reporting, where either a written report or oral advice was provided to the Company that EY concluded was an important factor considered by the Company in reaching a decision as to any accounting, auditing or financial reporting issue; or (ii) any matter that was either the subject of a disagreement (as defined in Item 304(a)(1)(iv) of Regulation S-K and related instructions) or a reportable event (as defined in Item 304(a)(1)(v) of Regulation S-K). The Company has provided GT with a copy of this Current Report.
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WHERE YOU CAN FIND MORE INFORMATION
We have filed with the SEC a registration statement on Form S-1 (including the exhibits, schedules and amendments thereto) under the Securities Act, with respect to our Class A common stock offered hereby. This prospectus does not contain all of the information set forth in the registration statement and the exhibits and schedules thereto. For further information with respect to the Class A common stock offered hereby, we refer you to the registration statement and the exhibits and schedules filed therewith. Statements contained in this prospectus as to the contents of any contract, agreement or other document are summaries of the material terms of such contract, agreement or other document and are not necessarily complete. With respect to each of these contracts, agreements or other documents filed as an exhibit to the registration statement, reference is made to the exhibits for a more complete description of the matter involved. The SEC maintains a website that contains reports, proxy and information statements and other information regarding registrants that file electronically with the SEC. The address of the SEC’s website is www.sec.gov. A copy of the registration statement, of which this prospectus forms a part, and the exhibits and schedules thereto may be downloaded from the SEC’s website.
As a result of this offering, we will become subject to full information reporting requirements of the Exchange Act and will file with or furnish to the SEC periodic reports and other information. We intend to furnish our shareholders with annual reports containing our audited financial statements prepared in accordance with GAAP and certified by an independent public accounting firm. We also intend to furnish or make available to our shareholders quarterly reports containing our unaudited interim financial information, for the first three fiscal quarters of each fiscal year. Our website is located at www.x-energy.com. Following the completion of this offering, we intend to make our periodic reports and other information filed with or furnished to the SEC available, free of charge, through our website, as soon as reasonably practicable after those reports and other information are electronically filed with or furnished to the SEC. Information contained on our website or linked therein or otherwise connected thereto does not constitute part of nor is it incorporated by reference into this prospectus or the registration statement of which this prospectus forms a part.
199
INDEX TO FINANCIAL STATEMENTS
X-Energy, Inc.
| | Audited Financial Statements for the Year Ended December 31, 2025: | | | | | | | |
| |
Report of Ernst & Young LLP (PCAOB ID: 42)
|
| | | | F- | | |
| |
Consolidated Balance Sheet as of December 31, 2025
|
| | | | F- | | |
| |
Notes to Consolidated Balance Sheet
|
| | | | F- | | |
X-Energy Reactor Company, LLC
Audited Financial Statements for the Year Ended December 31, 2024 and 2023:
| | | | | | F-2 | | | |
| | | | | | F-3 | | | |
| | | | | | F-4 | | | |
| | | | | | F-5 | | | |
| | | | | | F-6 | | | |
| | | | | | F-7 | | | |
| | | | | | F-8 | | |
Unaudited Condensed Financial Statements for the Nine Months Ended September 30, 2025 and 2024:
| | | | | | F-38 | | | |
| | | | | | F-39 | | | |
| | | | | | F-40 | | | |
| | | | | | F-41 | | | |
| | | | | | F-42 | | |
F-1
Report of Independent Registered Public Accounting Firm
To the Members and Board of Directors of X-Energy Reactor Company, LLC
Opinion on the Financial Statements
We have audited the accompanying consolidated balance sheet of X-Energy Reactor Company, LLC (the Company) as of December 31, 2024 the related consolidated statements of operations and comprehensive loss, changes in members’ deficit and mezzanine equity and cash flows for the year then ended and the related notes (collectively referred to as the “consolidated financial statements”). In our opinion, the consolidated financial statements present fairly, in all material respects, the financial position of the Company at December 31, 2024, and the results of its operations and its cash flows for the year then ended in conformity with U.S. generally accepted accounting principles.
Basis for Opinion
These financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on the Company’s 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 and in accordance with auditing standards generally accepted in the United States of America. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement, whether due to error or fraud. The Company is not required to have, nor were we engaged to perform, an audit of its internal control over financial reporting. As part of our audit, we are required to obtain an understanding of internal control over financial reporting but not for the purpose of expressing an opinion on the effectiveness of the Company’s internal control over financial reporting. Accordingly, we express no such opinion.
Our audit included performing procedures to assess the risks of material misstatement of the financial statements, whether due to error or fraud, and performing procedures that respond to those risks. Such procedures included examining, on a test basis, evidence regarding the amounts and disclosures in the financial statements. Our audits also included evaluating the accounting principles used and significant estimates made by management, as well as evaluating the overall presentation of the financial statements. We believe that our audit provides a reasonable basis for our opinion.
/s/ Ernst & Young LLP
We have served as the Company’s auditor since 2025.
Tysons, VA
November 11, 2025
F-2
REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM
Board of Directors and Members
X-Energy Reactor Company, LLC
X-Energy Reactor Company, LLC
Opinion on the financial statements
We have audited the accompanying consolidated balance sheet of X-Energy Reactor Company, LLC (a Delaware limited liability company) and subsidiaries (the “Company”) as of December 31, 2023, the related consolidated statements of operations and comprehensive loss, changes in members’ deficit and mezzanine equity, and cash flows for the year ended December 31, 2023, and the related notes (collectively referred to as the “consolidated financial statements”). In our opinion, the consolidated financial statements present fairly, in all material respects, the financial position of the Company as of December 31, 2023, and the results of its operations and its cash flows for the year ended December 31, 2023, 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 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 and in accordance with auditing standards generally accepted in the United States of America. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement, whether due to error or fraud. The Company is not required to have, nor were we engaged to perform, an audit of its internal control over financial reporting. As part of our audit we are required to obtain an understanding of internal control over financial reporting but not for the purpose of expressing an opinion on the effectiveness of the Company’s internal control over financial reporting. Accordingly, we express no such opinion.
Our audit included performing procedures to assess the risks of material misstatement of the financial statements, whether due to error or fraud, and performing procedures that respond to those risks. Such procedures included examining, on a test basis, evidence regarding the amounts and disclosures in the financial statements. Our audit also included evaluating the accounting principles used and significant estimates made by management, as well as evaluating the overall presentation of the financial statements. We believe that our audit provides a reasonable basis for our opinion.
/s/ GRANT THORNTON LLP
We served as the Company’s auditor from 2022 to 2025.
Arlington, Virginia
November 11, 2025
November 11, 2025
F-3
X-ENERGY REACTOR COMPANY, LLC
CONSOLIDATED BALANCE SHEETS
(in thousands, except units)
(in thousands, except units)
| | | |
December 31,
2024 |
| |
December 31,
2023 |
| ||||||
| ASSETS | | | | | | | | | | | | | |
| Current assets | | | | | | | | | | | | | |
|
Cash and cash equivalents
|
| | | $ | 514,600 | | | | | $ | 14,398 | | |
|
Accounts receivable
|
| | | | 1,212 | | | | | | 10,287 | | |
|
Unbilled receivables and contract assets
|
| | | | 27,211 | | | | | | 29,001 | | |
|
Prepaid and other current assets
|
| | | | 2,894 | | | | | | 1,477 | | |
|
Due from related parties
|
| | | | 15,973 | | | | | | 3,507 | | |
|
Total current assets
|
| | | | 561,890 | | | | | | 58,670 | | |
|
Property and equipment, net
|
| | | | 5,828 | | | | | | 4,067 | | |
|
Operating lease right-of-use assets
|
| | | | 11,003 | | | | | | 12,188 | | |
|
Other long-term assets
|
| | | | 789 | | | | | | 646 | | |
|
Total assets
|
| | | $ | 579,510 | | | | | $ | 75,571 | | |
| LIABILITIES, MEZZANINE EQUITY, AND MEMBERS’ DEFICIT | | | | | | | | | | | | | |
| Current liabilities | | | | | | | | | | | | | |
|
Short-term borrowings
|
| | | $ | 18,537 | | | | | $ | 56,568 | | |
|
Accounts payable
|
| | | | 2,327 | | | | | | 8,023 | | |
|
Accrued liabilities
|
| | | | 35,379 | | | | | | 44,436 | | |
|
Derivative liability
|
| | | | — | | | | | | 6,153 | | |
|
Due to related parties
|
| | | | 8,480 | | | | | | 18,148 | | |
|
Total current liabilities
|
| | | | 64,723 | | | | | | 133,328 | | |
| Long-term liabilities | | | | | | | | | | | | | |
|
Long-term debt
|
| | | | — | | | | | | 121,240 | | |
|
Long-term operating lease liabilities
|
| | | | 10,338 | | | | | | 11,674 | | |
|
Warrant liabilities
|
| | | | 50,634 | | | | | | 8,444 | | |
|
Total liabilities
|
| | | | 125,695 | | | | | | 274,686 | | |
| Mezzanine equity | | | | | | | | | | | | | |
|
Class A Common Units: 328,688,824 units authorized, 3,128,026 units issued and outstanding as of December 31, 2024, and 127,000,000 units authorized, 3,128,026 units issued and outstanding as of December 31, 2023
|
| | | | 1,800 | | | | | | 1,800 | | |
|
Class B Common Units: 34,043,242 units authorized, 13,960,705 units issued and outstanding as of December 31, 2024, and 15,520,671 units authorized, 10,139,568 units issued and outstanding as of December 31, 2023
|
| | | | 90,859 | | | | | | 74,250 | | |
|
Series A redeemable convertible preferred units: 90,625,588 units authorized, issued and outstanding as of December 31, 2024 and 2023; liquidation preference of $52,146 as of December 31, 2024 and 2023
|
| | | | 218,408 | | | | | | 218,408 | | |
|
Series A-1 redeemable convertible preferred units: 8,808,351 units authorized, issued and outstanding as of December 31, 2024 and 2023; liquidation preference of $67,250 as of December 31, 2024 and 2023
|
| | | | 21,477 | | | | | | 21,477 | | |
|
Series B redeemable convertible preferred units: 11,643,171 units authorized, issued and outstanding as of
December 31, 2024 and 2023; liquidation preference of $117,030 as of December 31, 2024 and $113,845 as of December 31, 2023 |
| | | | 101,382 | | | | | | 101,382 | | |
|
Series C redeemable convertible preferred units: 65,185,243 units authorized; 37,093,420 units issued and outstanding as of December 31, 2024, and 65,185,243 units authorized; 16,340,900 units issued and outstanding as of December 31, 2023; liquidation preference of $283,201 as of December 31, 2024 and $124,760 as of December 31, 2023
|
| | | | 230,987 | | | | | | 99,458 | | |
|
Series C-1 redeemable convertible preferred units: 148,122,321 units authorized; 99,672,593 units issued and outstanding as of December 31, 2024, and zero authorized and outstanding as of December 31, 2023; liquidation preference of $808,220 as of December 31, 2024
|
| | | | 635,463 | | | | | | — | | |
|
Total mezzanine equity
|
| | | | 1,300,376 | | | | | | 516,775 | | |
|
Accumulated deficit
|
| | | | (846,567) | | | | | | (716,769) | | |
|
Accumulated other comprehensive income
|
| | | | 6 | | | | | | 879 | | |
|
Total members’ deficit
|
| | | | (846,561) | | | | | | (715,890) | | |
|
Total liabilities, mezzanine equity, and members’ deficit
|
| | | $ | 579,510 | | | | | $ | 75,571 | | |
F-4
X-ENERGY REACTOR COMPANY, LLC
CONSOLIDATED STATEMENTS OF OPERATIONS AND COMPREHENSIVE LOSS
(in thousands)
(in thousands)
| | | |
Year Ended December 31,
|
| |||||||||
| | | |
2024
|
| |
2023
|
| ||||||
|
Services revenue(1)
|
| | | $ | 83,986 | | | | | $ | 121,877 | | |
|
Grant income
|
| | | | 36,166 | | | | | | 11,165 | | |
|
Total revenues and grant income
|
| | | $ | 120,152 | | | | | $ | 133,042 | | |
| Operating expenses | | | | | | | | | | | | | |
|
Direct costs
|
| | | | 130,115 | | | | | | 199,586 | | |
|
Selling, general and administrative
|
| | | | 111,887 | | | | | | 68,693 | | |
|
Research and development
|
| | | | 1,662 | | | | | | 2,150 | | |
|
Total operating expenses
|
| | | | 243,664 | | | | | | 270,429 | | |
|
Operating loss
|
| | | | (123,512) | | | | | | (137,387) | | |
| Other income (expense) | | | | | | | | | | | | | |
|
Interest expense
|
| | | | (16,190) | | | | | | (8,262) | | |
|
Interest income
|
| | | | 2,833 | | | | | | 178 | | |
|
Other income (expense), net
|
| | | | 10,909 | | | | | | (85,749) | | |
|
Total other income (expense), net
|
| | | | (2,448) | | | | | | (93,833) | | |
|
Net loss
|
| | | $ | (125,960) | | | | | $ | (231,220) | | |
| Other comprehensive income (loss) | | | | | | | | | | | | | |
|
Foreign currency translation adjustment
|
| | | | 474 | | | | | | 69 | | |
|
Reclassification of OCI for conversion of Series C-1 and Series C-2 Notes
|
| | | | 4,873 | | | | | | (1,721) | | |
|
Changes in fair value of liabilities under fair value option attributable to changes in instrument-specific credit risk
|
| | | | (6,220) | | | | | | (4,474) | | |
|
Other comprehensive loss
|
| | | | (873) | | | | | | (6,126) | | |
|
Comprehensive loss
|
| | | $ | (126,833) | | | | | $ | (237,346) | | |
(1)
Includes related party revenue of $27,555 and $5,937 for the years ended December 31, 2024 and 2023, respectively.
F-5
X-ENERGY REACTOR COMPANY, LLC
CONSOLIDATED STATEMENTS OF CHANGES IN MEMBERS’ DEFICIT AND MEZZANINE EQUITY
(in thousands, except units)
(in thousands, except units)
| | | |
Accumulated
Deficit |
| |
Accumulated
Other Comprehensive Income (Loss) |
| |
Total
Members’ Deficit |
| | |
Class A
Common Units |
| |
Class B
Common Units |
| |
Series A
Preferred Units |
| |
Series A-1
Preferred Units |
| |
Series B
Preferred Units |
| |
Series C
Preferred Units |
| |
Series C-1
Preferred Units |
| |
Total
Mezzanine Equity |
| |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| |
Units
|
| |
Amount
|
| |
Units
|
| |
Amount
|
| |
Units
|
| |
Amount
|
| |
Unit
|
| |
Amount
|
| |
Units
|
| |
Amount
|
| |
Unit
|
| |
Amount
|
| |
Unit
|
| |
Amount
|
| |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
|
Balance, January 1, 2023
|
| | | $ | (437,886) | | | | | $ | 7,005 | | | | | $ | (430,881) | | | | | | | 3,128,026 | | | | | $ | 1,800 | | | | | | 3,406,500 | | | | | $ | 13,940 | | | | | | 90,625,588 | | | | | $ | 218,408 | | | | | | — | | | | | $ | — | | | | | | 11,643,171 | | | | | $ | 101,382 | | | | | | — | | | | | $ | — | | | | | | — | | | | | $ | — | | | | | $ | 335,530 | | |
|
Unit-based compensation
|
| | | | (47,663) | | | | | | — | | | | | | (47,663) | | | | | | | — | | | | | | — | | | | | | 1,312,250 | | | | | | 53,497 | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | 53,497 | | |
|
Issuance of units
|
| | | | — | | | | | | — | | | | | | — | | | | | | | — | | | | | | — | | | | | | 5,421,068 | | | | | | 6,813 | | | | | | — | | | | | | — | | | | | | 8,808,351 | | | | | | 21,477 | | | | | | — | | | | | | — | | | | | | 10,383,498 | | | | | | 52,156 | | | | | | — | | | | | | — | | | | | | 80,446 | | |
|
Conversion of Series C-1 Convertible Notes into Series C Preferred Units
|
| | | | — | | | | | | — | | | | | | — | | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | 5,957,402 | | | | | | 47,302 | | | | | | — | | | | | | — | | | | | | 47,302 | | |
|
Net Loss
|
| | | | (231,220) | | | | | | — | | | | | | (231,220) | | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | |
|
Foreign Currency Translation Adjustment
|
| | | | — | | | | | | 69 | | | | | | 69 | | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | |
|
Changes in fair value of liabilities under
fair value option attributable to changes in instrument specific credit risk |
| | | | — | | | | | | (4,474) | | | | | | (4,474) | | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | |
|
Reclassification of OCI for conversion of
C-1 Convertible Notes |
| | | | — | | | | | | (1,721) | | | | | | (1,721) | | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | |
|
Balance, December 31, 2023
|
| | | | (716,769) | | | | | | 879 | | | | | | (715,890) | | | | | | | 3,128,026 | | | | | | 1,800 | | | | | | 10,139,818 | | | | | | 74,250 | | | | | | 90,625,588 | | | | | | 218,408 | | | | | | 8,808,351 | | | | | | 21,477 | | | | | | 11,643,171 | | | | | | 101,382 | | | | | | 16,340,900 | | | | | | 99,458 | | | | | | — | | | | | | — | | | | | | 516,775 | | |
|
Unit-based compensation
|
| | | | (3,838) | | | | | | — | | | | | | (3,838) | | | | | | | — | | | | | | — | | | | | | 694,000 | | | | | | 4,988 | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | 4,988 | | |
|
Issuance of Class B Units in conjunction
with the issuance and modification of debt |
| | | | — | | | | | | — | | | | | | — | | | | | | | — | | | | | | — | | | | | | 2,369,752 | | | | | | 9,061 | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | 9,061 | | |
|
Issuance of Class B Units in conjunction
with the conversion of C-1 Notes to Series C Preferred Units |
| | | | — | | | | | | — | | | | | | — | | | | | | | — | | | | | | — | | | | | | 757,135 | | | | | | 2,560 | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | 2,560 | | |
|
Conversion of Series C-1 Notes into Series C Preferred Units
|
| | | | — | | | | | | — | | | | | | — | | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | 3,210,405 | | | | | | 27,138 | | | | | | — | | | | | | — | | | | | | 27,138 | | |
|
Exercise of the October 2022
Warrants |
| | | | — | | | | | | — | | | | | | — | | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | 582,094 | | | | | | 5,175 | | | | | | — | | | | | | — | | | | | | 5,175 | | |
|
Conversion of C-2 Notes into Series C-Preferred Units
|
| | | | — | | | | | | — | | | | | | — | | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | 16,960,021 | | | | | | 99,216 | | | | | | — | | | | | | — | | | | | | 99,216 | | |
|
Issuance of Series C-1 Preferred Units, net of issuance costs
|
| | | | — | | | | | | — | | | | | | — | | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | 96,575,116 | | | | | | 615,715 | | | | | | 615,715 | | |
|
Conversion of debt into Series C-1 Preferred Units, net of issuance
costs |
| | | | — | | | | | | — | | | | | | — | | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | 3,097,477 | | | | | | 19,748 | | | | | | 19,748 | | |
|
Net Loss
|
| | | | (125,960) | | | | | | — | | | | | | (125,960) | | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | |
|
Foreign Currency Translation Adjustment
|
| | | | — | | | | | | 474 | | | | | | 474 | | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | |
|
Changes in fair value of liabilities under
fair value option attributable to changes in instrument specific credit risk |
| | | | — | | | | | | (6,220) | | | | | | (6,220) | | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | |
|
Reclassification of OCI for conversion of
C-1 and C-2 Notes |
| | | | — | | | | | | 4,873 | | | | | | 4,873 | | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | |
|
Balance, December 31, 2024
|
| | | $ | (846,567) | | | | | $ | 6 | | | | | $ | (846,561) | | | | | | | 3,128,026 | | | | | $ | 1,800 | | | | | | 13,960,705 | | | | | $ | 90,859 | | | | | | 90,625,588 | | | | | $ | 218,408 | | | | | | 8,808,351 | | | | | $ | 21,477 | | | | | | 11,643,171 | | | | | $ | 101,382 | | | | | | 37,093,420 | | | | | $ | 230,987 | | | | | | 99,672,593 | | | | | $ | 635,463 | | | | | $ | 1,300,376 | | |
F-6
X-ENERGY REACTOR COMPANY, LLC
CONSOLIDATED STATEMENTS OF CASH FLOWS
(in thousands)
(in thousands)
| | | |
2024
|
| |
2023
|
| ||||||
| Cash flows from operating activities: | | | | | | | | | | | | | |
|
Net loss
|
| | | $ | (125,960) | | | | | $ | (231,220) | | |
| Adjustments to reconcile net loss to net cash used in operating activities: | | | | | | | | | | | | | |
|
Depreciation and amortization
|
| | | | 913 | | | | | | 684 | | |
|
Unit-based compensation
|
| | | | 1,150 | | | | | | 5,834 | | |
|
Loss on extinguishment of debt
|
| | | | 7,380 | | | | | | — | | |
|
Loss on issuance of Series C Preferred Units
|
| | | | — | | | | | | 1,170 | | |
|
Gain on conversion of C-1 & C-2 Notes
|
| | | | (2,757) | | | | | | — | | |
|
Non-cash selling, general, and administrative expenses
|
| | | | 55,252 | | | | | | — | | |
|
Payable in-kind interest
|
| | | | 3,792 | | | | | | 424 | | |
|
Mark-to-market gain on warrant liabilities
|
| | | | (7,887) | | | | | | (2,531) | | |
|
Mark-to-market loss on C-1 & C-2 Notes
|
| | | | 9,113 | | | | | | 27,694 | | |
|
Mark-to-market (gain) loss on derivative liabilities
|
| | | | (10,065) | | | | | | 2,542 | | |
|
Mark-to-market gain on 2024 Financial Instrument
|
| | | | (12,266) | | | | | | — | | |
|
Write-off of deferred SPAC transaction fees
|
| | | | — | | | | | | 22,629 | | |
|
Reclassification of OCI for conversion of C-1 & C-2 Notes
|
| | | | 4,873 | | | | | | (1,721) | | |
|
Amortization of deferred financing costs, debt discount, and other
|
| | | | 11,857 | | | | | | 2,341 | | |
| Changes in operating assets and liabilities: | | | | | | | | | | | | | |
|
Accounts receivable and unbilled receivables
|
| | | | 16,044 | | | | | | (174) | | |
|
Prepaid and other current assets
|
| | | | (1,416) | | | | | | 1,294 | | |
|
Due from related parties
|
| | | | (12,466) | | | | | | (3,066) | | |
|
Operating lease right-of use assets
|
| | | | 2,636 | | | | | | 3,544 | | |
|
Accounts payable and accrued liabilities
|
| | | | (21,301) | | | | | | 5,630 | | |
|
Payment of payable-in-kind interest
|
| | | | (4,147) | | | | | | — | | |
|
Deferred transaction costs
|
| | | | — | | | | | | 3,284 | | |
|
Other long-term assets
|
| | | | 206 | | | | | | (450) | | |
|
Due to related parties
|
| | | | (9,668) | | | | | | 3,950 | | |
|
Operating lease liabilities
|
| | | | (1,442) | | | | | | (1,438) | | |
|
Net cash used in operating activities
|
| | | $ | (96,159) | | | | | $ | (159,580) | | |
| Cash flows from investing activities: | | | | | | | | | | | | | |
|
Capital expenditures
|
| | | | (4,162) | | | | | | (2,978) | | |
|
Reimbursement of capital expenditures under government grant
|
| | | | 2,297 | | | | | | 1,080 | | |
|
Net cash used in investing activities
|
| | | $ | (1,865) | | | | | $ | (1,898) | | |
| Cash flows from financing activities: | | | | | | | | | | | | | |
|
Repayments on bridge loans
|
| | | | (53,800) | | | | | | — | | |
|
Borrowings on bridge loans
|
| | | | 49,598 | | | | | | 24,202 | | |
|
Repayments on lines of credit
|
| | | | (98,843) | | | | | | (44,653) | | |
|
Borrowings from lines of credit
|
| | | | 89,455 | | | | | | 21,688 | | |
|
Proceeds from C-2 Notes
|
| | | | — | | | | | | 28,000 | | |
|
Payments of mezzanine equity issuance costs
|
| | | | (10,760) | | | | | | — | | |
|
Payment of debt issuance costs
|
| | | | (3,793) | | | | | | (5,432) | | |
|
Proceeds from Series C Preferred Units
|
| | | | — | | | | | | 79,276 | | |
|
Proceeds from Series C-1 Preferred Units
|
| | | | 626,483 | | | | | | — | | |
|
Net cash provided by financing activities
|
| | | $ | 598,340 | | | | | $ | 103,081 | | |
|
Net effect of exchange rate
|
| | | | (114) | | | | | | 7 | | |
|
Net increase (decrease) in cash and cash equivalents
|
| | | | 500,202 | | | | | | (58,390) | | |
|
Cash and cash equivalents at beginning of period
|
| | | | 14,398 | | | | | | 72,788 | | |
|
Cash and cash equivalents at end of period
|
| | | $ | 514,600 | | | | | $ | 14,398 | | |
F-7
X-ENERGY REACTOR COMPANY, LLC
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
NOTE 1 — ORGANIZATION AND NATURE OF BUSINESS
Company Overview
X-Energy Reactor Company, LLC (“X-energy” or the “Company” or “its”) is a Delaware limited liability company formed on December 14, 2018, and is the predecessor for financial reporting purposes of X-energy, LLC, a Maryland limited liability company founded in 2009. The Company is headquartered in Rockville, Maryland. The Company is a developer of advanced small modular nuclear reactors and fuel technology for clean energy generation.
On December 5, 2022, the Company entered into a Business Combination Agreement (“BCA”) with Ares Acquisition Corporation (“AAC”), a publicly traded special purpose acquisition company (“SPAC”), to effect a merger of the Company and AAC. On October 31, 2023, the Company and AAC mutually agreed to terminate the BCA.
NOTE 2 — SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES AND RECENT ACCOUNTING PRONOUNCEMENTS
Basis of Presentation
The consolidated financial statements for X-Energy Reactor Company, LLC as of and for the years ended December 31, 2024 and 2023, include the accounts of the Company’s wholly owned and consolidated subsidiaries. The consolidated financial statements have been prepared pursuant to the accounting principles generally accepted in the United States of America (“U.S. GAAP”). All intercompany balances and transactions have been eliminated in consolidation.
Use of Estimates
The preparation of the Company’s financial statements in conformity with U.S. GAAP requires it to make estimates and assumptions that affect the reported amounts of assets and liabilities and the disclosures of contingent assets and liabilities as of the date of the financial statements and the reported amounts of revenues and expenses for the reporting period. Some of the more significant estimates include estimates of costs to complete long-term contracts and the associated revenues, and the valuation of profits interests, unit-based compensation, preferred units, warrants, exchanged debt, and liabilities measured at fair value. Due to the inherent uncertainty involved in making estimates, actual results could differ from those estimates which could have a material effect on the financial condition and results of operations in future periods.
The Company bases its estimates and assumptions on historical experience and other factors, including the current economic environment and on various other judgments that it believes to be reasonable under the circumstances. The Company adjusts such estimates and assumptions when facts and circumstances dictate. Changes in those estimates resulting from continuing changes in the economic environment will be reflected in the financial statements in future periods.
Certain Significant Risks and Uncertainties
Financial instruments that potentially subject the Company to concentrations of credit risk consist principally of cash and cash equivalents and accounts receivable. By their nature, all such financial instruments involve risks, including the credit risk of nonperformance by counterparties. The Company generally does not require collateral to support the obligations of the counterparties and cash levels held at banks may be in excess of federally insured limits. The Company limits its exposure to credit loss by maintaining its cash and cash equivalents at highly rated financial institutions. The Company has not experienced material losses on its deposits of cash and cash equivalents. Further, the Company’s revenue and credit relationships are primarily concentrated within the United States Government which represents a concentration risk but a low credit risk.
F-8
For the year ended December 31, 2024, two customers, the United States Government and the Dow Chemical Company, accounted for 74% and 22%, respectively, of the Company’s total revenue and grant income. For the year ended December 31, 2023, the United States Government accounted for 94% of the Company’s total revenue and grant income. Refer to Note 3 — Revenue Recognition for further disaggregation of revenue and grant income by customer for the years ended December 31, 2024 and 2023.
As of December 31, 2024 and 2023, the Company’s receivable balances related to services revenue and government grants with the United States Department of Energy (“DoE”) and United States Department of Defense (“DoD”) are as follows. Refer to Note 14 — Related Party Transactions for further information on receivable balances with Dow Chemical Company (“Dow”).
| | | |
December 31,
2024 |
| |
December 31,
2023 |
| ||||||
| Accounts Receivable | | | | | | | | | | | | | |
|
DoE
|
| | | $ | — | | | | | $ | 9,461 | | |
|
DoD
|
| | | | — | | | | | | 733 | | |
| Unbilled Receivables and Contract Assets | | | | | | | | | | | | | |
|
DoE
|
| | | $ | 23,794 | | | | | $ | 27,404 | | |
|
DoD
|
| | | | 2,690 | | | | | | 1,482 | | |
Other Comprehensive Income (Loss)
Other comprehensive income (loss) refers to revenues, expenses, gains, and losses that under generally accepted accounting principles (GAAP) are included in comprehensive income but excluded from net income. The components of the Company’s other comprehensive income (loss) consist of foreign currency translation adjustments, the reclassification of other comprehensive income for the conversion of Series C-1 and C-2 Notes, and the change in fair value of financial liabilities accounted for pursuant to the fair value option attributable to changes in instrument-specific credit risk.
The components of accumulated other comprehensive income for the years ended December 31, 2024 and December 2023 are as follows:
| | | |
Changes in fair value of
liabilities under fair value option attributable to changes in instrument specific credit risk |
| |
Reclassification of
OCI for conversion of Series C-1 and Series C-2Notes |
| |
Foreign currency
translation adjustment |
| |
Total
|
| ||||||||||||
|
Accumulated other comprehensive income (loss), balance at December 31, 2022
|
| | | $ | 6,777 | | | | | $ | — | | | | | $ | 228 | | | | | $ | 7,005 | | |
|
Other comprehensive income (loss)
|
| | | | (4,474) | | | | | | (1,721) | | | | | | 69 | | | | | | (6,126) | | |
|
Accumulated other comprehensive loss, balance at December 31, 2023
|
| | | | 2,303 | | | | | | (1,721) | | | | | | 297 | | | | | | 879 | | |
|
Other comprehensive income (loss)
|
| | | | (6,220) | | | | | | 4,873 | | | | | | 474 | | | | | | (873) | | |
|
Accumulated other comprehensive income
(loss), balance at December 31, 2024 |
| | | $ | (3,917) | | | | | $ | 3,152 | | | | | $ | 771 | | | | | $ | 6 | | |
Cash and Cash Equivalents
Cash and cash equivalents consist primarily of cash deposits, cash held in financial institutions and short-term investments purchased with an original maturity of three months or less. The carrying value of cash equivalents approximates fair value because of the short-term nature of these investments. The Company maintains its cash in bank deposit accounts with high credit quality financial institutions which, at times, may exceed the federally insured limit. The Company does not believe it is exposed to any significant credit risk regarding these deposits.
F-9
Accounts Receivable
Accounts receivable are presented at the invoiced receivable amounts, less any allowance for any potential expected uncollectible amounts, and do not bear interest. The Company estimates allowance for credit losses based on the credit worthiness of each customer, historical collections experience, forward looking information, adverse situations that may affect a customer’s ability to pay, and both microeconomic and macroeconomic factors. The Company grants uncollateralized credit in the form of accounts receivable to its customers. The Company’s receivables are heavily concentrated from two agencies of the United States Government, the DoE and DoD. Historically, the Company has not experienced any significant credit-related losses, and management does not believe that any government agencies represent a significant credit risk. Accordingly, historical write-offs of accounts receivable have not occurred and as of December 31, 2024 and 2023, no reserve was recorded.
Customer payments on contracts are typically due within 30 days of billing, depending on the contract.
Prepaid and Other Current Assets
Prepaid and other current assets, primarily consisting of prepaid service fees, software and other general prepayments, amounted to $2.9 million and $1.5 million as of December 31, 2024 and 2023, respectively.
Deferred Financing Costs
The Company has recorded deferred financing costs incurred in conjunction with its debt obligations that are held at amortized cost. The Company amortizes deferred financing costs over the remaining life of the related debt and records the amortization within interest expense.
Debt issuance costs associated with debt obligations remeasured at fair value at each reporting period under the fair value option are expensed in the period incurred. For the year ended December 31, 2023, the Company incurred $1.1 million in debt issuance costs associated with the issuance of additional C-2 Notes, which was recorded within interest expense on the consolidated statement of operations and comprehensive loss. The Company did not incur further material issuance costs related to convertible debt during the year ended December 31, 2024.
In connection with the issuance and amendments of the non-convertible debt, the Company incurred third-party debt issuance costs in the amount of $2.9 million and $1.7 million during the years ended December 31, 2024 and 2023, respectively. The debt issuance costs are treated as a debt discount and are amortized over the term of the related loan. During the years ended December 31, 2024 and 2023, $4.8 million and $0.6 million, respectively, of amortization expense related to the discount created from the deferred financing costs was recorded to interest expense on the consolidated statements of operations.
The Company records deferred financing costs incurred in conjunction with the issuance of preferred units as a reduction of mezzanine equity on the consolidated balance sheets. For the year ended December 31, 2024, the Company incurred $11.1 million in issuance costs associated with the issuance of the Series C-1 Preferred Units.
Property and Equipment, net
Property and equipment, net is stated at cost, less accumulated depreciation and amortization and any accumulated impairments. Depreciation and amortization is recognized using the straight-line method over the following estimated useful lives of assets and is recorded within selling, general, and administrative expenses on the consolidated statements of operations and comprehensive loss:
|
Asset
|
| |
Useful Life
|
|
|
Equipment and materials
|
| |
5 – 35 years
|
|
|
Computer equipment and software
|
| |
3 – 5 years
|
|
|
Office furniture and fixtures
|
| |
2 – 7 years
|
|
|
Leasehold improvements
|
| |
Shorter of lease term or 10 years
|
|
F-10
The costs of maintenance and repairs that do not materially prolong the useful life of an asset are expensed as incurred. Asset betterments are capitalized. Costs for property and equipment not yet placed into service are capitalized as construction-in-progress and will be depreciated in accordance with the above guidelines once placed into service.
Government Grants
U.S. GAAP for profit-oriented entities does not provide prescriptive guidance applicable to government grants. Under the Company’s accounting policy for government grants and consistent with the International Accounting Standard 20 (IAS 20) Accounting for Government Grants and Disclosure of Government Assistance, the Company recognizes government grants when there is reasonable assurance that the Company will comply with the conditions attached to the grant arrangement and the grant will be received. The Company evaluates the conditions of each grant as of each reporting period to ensure that the Company has reached reasonable assurance of meeting the conditions of each grant arrangement and that it is expected that the grant will be received as a result of meeting the necessary conditions. The Company has elected to record grants related to assets as a deduction in calculating the carrying value of the asset. The Company has elected to record grants related to income separately from revenues on the Consolidated Statements of Operations and Comprehensive Loss as the goods and services provided for under the grant are consistent with the operating activities of the Company. The expenses related to grant income are recorded on a gross basis as direct costs. Grant income and direct costs related to activities of third parties including subcontractors and sub-awardees are recorded on a gross basis when the Company has the power to redirect the funds from grantor to a different party, or retain those funds itself, in order to meet the conditions of the grant. Factors considered, among others, include whether the Company is responsible for and has discretion over whether to engage third parties, and if so engaged, which third parties to engage and on what terms.
Impairment of Long-Lived Assets
Long-lived assets are reviewed for impairment whenever events or changes in circumstances indicate that the carrying amount of an asset or group of assets may be greater than fair market value as of the reporting date. Such events or circumstances may include significant decreases in the market price of the asset, significant adverse changes in the business climate or legal factors, accumulation of costs significantly in excess of the amount originally expected for the acquisition or construction of the asset, current period cash flow or operating losses combined with a history of losses or a forecast of continuing losses associated with the use of the asset, or a current expectation that the asset will more likely than not be sold or disposed of significantly before the end of its estimated useful life. If an impairment indicator is present, the Company evaluates recoverability by a comparison of the carrying amount of the asset to the future undiscounted net cash flows expected to be generated by the asset. If the carrying value of a long-lived asset is not recoverable (i.e., it exceeds the expected future undiscounted cash flows), it is impaired, and the impairment loss is measured as the difference between the carrying value of the asset and its fair value. No impairment losses were recognized for the years ended December 31, 2024 and 2023.
Deferred Revenue
The Company recognizes a contract liability, referred to as deferred revenue in its consolidated financial statements, when the Company receives a payment from customers for services that have yet to be delivered or completely delivered. See Note 3 — Revenue Recognition for further discussion on deferred revenue balances.
Financial Instruments and Fair Value Measurements
The carrying amount reflected in the Company’s consolidated balance sheets for cash and cash equivalents, accounts receivable, and accounts payable approximate fair value due to the short-term maturities of these instruments. For the Company’s financial assets or liabilities that are carried at fair value and remeasured on a recurring basis, the Company utilizes valuation techniques that maximize the use of observable inputs and minimize the use of unobservable inputs to the extent possible. The Company estimates fair value based on assumptions that active market participants would use in pricing an asset or liability in the principal or most advantageous market.
F-11
When considering market participant assumptions in fair value measurements, the following fair value hierarchy distinguishes between observable and unobservable inputs. Fair value measurements are categorized according to the criteria below based on the lowest level of input that is significant to the overall fair value measurement of the instrument:
•
Level 1 inputs: Quoted prices (unadjusted) in active markets for identical assets or liabilities that the reporting entity can access at the measurement date;
•
Level 2 inputs: Inputs other than quoted prices included within Level 1 that are observable for the asset or liability, either directly or indirectly; and
•
Level 3 inputs: Unobservable inputs for the asset or liability. These are used to measure fair value to the extent those observable inputs are not available, thereby allowing for situations in which there is minimal, if any, market activity for the asset or liability at the measurement date.
Refer to Note 13 — Fair Value Measurements for the financial assets and liabilities that are recorded at fair value on a recurring basis within the consolidated balance sheets.
Revenue and Cost Recognition
For the years ended December 31, 2024 and 2023, the Company generated all of its services revenue from contracts with customers, a substantial portion of which was generated from contracts with the U.S. Government. A majority of the Company’s contracts with the U.S. Government are generally subject to the Federal Acquisition Regulation (“FAR”) and are priced based on estimated costs of providing the contractual services.
The Company accounts for a contract when the parties have approved the contract and are committed to perform on it, the rights of each party and the payment terms are identified, the contract has commercial substance, and collection of substantially all of the consideration is probable.
The Company evaluates if its contracts are partially in the scope of ASC 606, Revenue from Contracts with Customers, and partially in the scope of other guidance. For contracts partially in the scope of other guidance, the Company separates and allocates the arrangement consideration to those components in accordance with ASC 606 unless the other guidance provides its own separation and allocation guidance.
At contract inception, the Company determines whether the services to be provided are to be accounted for as a single performance obligation or as multiple performance obligations. This evaluation requires professional judgment, and it may impact the timing and pattern of revenue recognition.
The Company’s contracts may include variable consideration, such as adjustments to pricing based on performance or other contractual terms. Variable consideration is estimated at contract inception and updated throughout the contract term as additional information becomes available. The Company includes variable consideration in the transaction price only to the extent that it is probable that a significant reversal of cumulative revenue recognized will not occur when the uncertainty associated with the variable consideration is resolved.
The Company generally recognizes revenue over time throughout the performance period as the customer simultaneously receives and consumes the benefits provided on services-type revenue arrangements. The Company satisfies its performance obligation as services are rendered. An input method is used for cost based contracts, based on the cost of services which correspond directly with the value of the Company’s performance completed to date. For fixed-fee contracts, the Company applies an input method — specifically the cost-to-cost approach — where revenue is recognized in proportion to costs incurred, reflecting progress towards complete satisfaction of the performance obligation.
Contract modifications are reviewed to determine whether they should be accounted for as part of the original performance obligation or as a separate contract. When a contract modification changes the scope or price and the additional performance obligations are at their standalone selling price, the original contract is terminated and the Company accounts for the change prospectively when the new services to be transferred are distinct from those already provided. When the contract modification includes services that are not distinct
F-12
from those already provided, the Company records a cumulative adjustment to revenue based on a remeasurement of progress towards the complete satisfaction of the not yet fully delivered performance obligation.
The Company utilizes other parties in the performance of some services. Using a control model, the Company evaluates whether it has promised to provide services to the customers as a principal or to arrange for services to be provided by another party as an agent. Based on the Company’s evaluation using a control model, the Company determined that in all of its performance obligations, it serves as a principal rather than an agent within its revenue arrangements. Revenue and the associated expenses are both reported on a gross basis within the consolidated statements of operations and comprehensive loss.
Direct Costs
Direct costs on the consolidated statements of operations and comprehensive loss include all costs directly attributable to providing services under contracts with customers and grants related to income, such as direct labor, direct materials and subcontracting costs. Indirect costs are allocated to direct costs in the same manner as such costs are defined in disclosure statements under U.S. Government Cost Accounting Standards.
Selling, General and Administrative Expense
Selling, general and administrative expenses consist of human capital related expenses for employees involved in general corporate functions, including executive management and administration, accounting, finance, tax, legal, information technology, marketing and human resources; rent relating to the Company’s office space; professional fees; non-cash consideration issued to customers; and other general corporate costs.
Other Income (Expense), Net
Other income (expense), net for the years ended December 31, 2024 and 2023 consists of the following (in thousands):
| | | |
Year Ended December 31,
|
| |||||||||
| | | |
2024
|
| |
2023
|
| ||||||
|
Foreign currency transaction (losses)
|
| | | $ | (685) | | | | | $ | (110) | | |
|
Mark-to-market loss on C-1 & C-2 Notes(1)
|
| | | | (9,113) | | | | | | (27,694) | | |
|
Loss on issuance of Series C Preferred Units(1)
|
| | | | — | | | | | | (1,170) | | |
|
Gain on conversion of C-1 & C-2 Notes(1)
|
| | | | 2,757 | | | | | | — | | |
|
Mark-to-market gain on warrant liabilities(1)
|
| | | | 7,887 | | | | | | 2,531 | | |
|
Mark-to-market gain (loss) on embedded derivatives(1)
|
| | | | 10,065 | | | | | | (2,542) | | |
|
Mark-to-market gain on 2024 Financial Instrument(1)
|
| | | | 12,266 | | | | | | — | | |
|
Reclassification of OCI for conversion of C-1 & C-2 Notes(1)
|
| | | | (4,873) | | | | | | 1,721 | | |
|
Loss on extinguishment of debt(1)
|
| | | | (7,380) | | | | | | — | | |
|
Write-off of SPAC transaction costs due to BCA termination
|
| | | | — | | | | | | (58,424) | | |
|
Other expense
|
| | | | (15) | | | | | | (61) | | |
|
Total other income (expense), net
|
| | | $ | 10,909 | | | | | $ | (85,749) | | |
(1)
Refer to Note 7 — Debt.
Research and Development
The Company conducts research and development activities related to the development and improvement of future technologies pertaining to nuclear reactor and fuel design engineering. The costs incurred for conducting the research and development primarily include equipment, material, and labor hours. Such costs of research and development are expensed in the period incurred.
F-13
Leases
The Company leases facilities including office space under non-cancelable lease contracts with terms greater than 12 months and the Company has classified these leases as operating leases. The Company does not have any material finance leases. When determining lease term, the Company considers any options to extend or terminate the lease when it is reasonably certain the Company will exercise such options.
The Company elected to account for lease and non-lease components related to office space and equipment as a single lease component. Leases with an initial term of 12 months or less are not included within the lease right-of-use (“ROU”) assets and lease liabilities recognized on the consolidated balance sheets, and instead the lease payments for those short-term leases are recognized on a straight-line basis over the lease term.
Lease ROU assets are calculated as the net present value of future payments plus any capitalized initial direct costs less any tenant improvements or lease incentives. Lease liabilities are calculated as the net present value of future payments. For leases that do not provide an implicit interest rate, the Company uses the incremental borrowing rate to calculate the lease liability. Upon lease modification, the Company remeasures the ROU asset and lease liability as of the modification date.
Lease expense for minimum operating lease payments is recognized on a straight-line basis over the lease term. Any variable non-lease components are not included within the lease ROU asset and lease liability on the consolidated balance sheets and instead are reflected as an expense in the period incurred.
Loss Contingencies
The Company accrues liabilities for loss contingencies when it is probable that a loss has been incurred on account of investigations, litigation, disputes, or claims related to its business activities and the amount of loss is reasonably estimable. When the amount of loss cannot be reasonably estimated, the Company will disclose contingent liabilities when there is a reasonable possibility that a loss or additional loss may have been incurred. The Company’s future earnings could be affected by changes in the assessments of the probability of a loss or changes in the estimates related to such matters.
Unit-Based Compensation
Unit-based compensation represents costs related to unit-based awards granted to employees and members of the Board of Directors. The Company recognizes unit-based compensation, utilizing the accelerated attribution method, based upon the estimated fair value of awards on the grant date for equity classified awards. Forfeitures are accounted for as they occur. The recognition period for these costs begins at either the applicable service inception date or grant date and continues throughout the requisite service period. Due to the contingently redeemable nature of Class B Common Units (inclusive of the Class B-1 Common Units and Class B-2 Common Units, as discussed in Note 11 — Member Units and Preferred Units and Note 12 — Unit-Based Compensation Expense), the Company classifies these units as mezzanine equity and records the redemption value as of the grant date for vested awards within mezzanine equity on the consolidated balance sheets. As of December 31, 2024 and 2023, $72.4 million and $67.4 million has been presented within mezzanine equity, and the excess of redemption value over grant date fair value for vested awards has been recorded within accumulated deficit on the consolidated balance sheets. Additionally, the Company does not believe that related contingent events and the redemption of the Class B Common Units is probable to occur.
Foreign Currency Translation
The functional currency of the Company’s foreign operations is the reported local currency. Translation adjustments result from translating the Company’s foreign subsidiaries’ financial statements into United States dollars. The balance sheet accounts of the Company’s foreign subsidiaries are translated into United States dollars using the exchange rate in effect at the balance sheet date. Revenue and expenses are translated using average exchange rates for each month during the fiscal year. The resulting translation gains or losses are recorded as a component of accumulated other comprehensive income (loss) in members’ deficit. The foreign currency gains and losses are not material for the periods presented.
F-14
Income Taxes
The Company is a limited liability company which is classified as a partnership for U.S. federal and state income tax purposes. Accordingly, the Company’s U.S. operations are not subject to income taxes in the U.S. The Company’s owners separately account for their pro rata share of the Company’s income, deductions, losses and credits annually. The Company’s foreign operations are subject to income taxes in the foreign jurisdictions in which they operate. Income tax expense and benefit were immaterial as of December 31, 2024 and 2023.
Embedded Derivatives
The Company reviews the terms of its financial instruments to determine whether there are features, such as redemption and interest rate adjustment features, which are required to be bifurcated and accounted for separately as derivative financial instruments. In circumstances where the host instrument contains more than one embedded derivative instrument that is required to be bifurcated, the bifurcated derivative instruments are accounted for as a single, compound derivative instrument. Bifurcated embedded derivatives are initially recorded at fair value and are then revalued at the end of each reporting period and immediately prior to the extinguishment of the financial instrument. Changes in fair value of bifurcated embedded derivatives are recognized in earnings in the period in which the change occurs.
Accounting Principles Recently Adopted
In March 2023, the FASB issued ASU No. 2023-01, Leases (Topic 842): Common Control Arrangements (“ASU 2023-01”), which requires that leasehold improvements associated with common control leases be amortized over the useful life of the leasehold improvements to the common control group, regardless of the lease term. ASU 2023-01 is effective for fiscal years beginning after December 15, 2023, including interim periods for those fiscal years. The Company adopted ASU 2023-01 on January 1, 2024, and there was no material impact on the consolidated financial statements.
In November 2023, the FASB issued ASU No. 2023-07, Segment Reporting (Topic 280): Improvements to Reportable Segment Disclosures (“ASU 2023-07”). ASU 2023-07 enhances segment reporting by requiring additional disclosures of significant segment expenses, interim period segment information, and other segment items for each reportable segment. ASU 2023-07 is effective for fiscal years beginning after December 15, 2023, including interim periods within those fiscal years, with early adoption permitted. The Company adopted ASU 2023-07 on January 1, 2024, and there was no material impact on the consolidated financial statements. The Company has accounted for segment reporting in accordance with ASU 2023-07.
Accounting Principles Not Yet Adopted
In December 2023, the FASB issued ASU No. 2023-09, Income Taxes (Topic 740): Improvements to Income Tax Disclosures (“ASU 2023-09”), to enhance the transparency and decision usefulness of income tax disclosures. ASU 2023-09 is effective for annual periods beginning after December 15, 2025 on a prospective basis and early adoption is permitted. The Company is currently evaluating the impact of the adoption of this standard on its consolidated financial statements and related disclosures.
In November 2024, the FASB issued ASU No. 2024-03, Income Statement — Reporting Comprehensive Income — Expense Disaggregation Disclosures (Subtopic 220-40): Disaggregation of Income Statement Expenses (“ASU 2024-03”), which requires public business entities to provide enhanced disclosures about certain categories of expenses in the notes to the financial statements. The guidance is intended to improve the transparency and decision usefulness of expense information provided to financial statement users. The ASU is effective for fiscal years beginning after December 15, 2026, and interim periods within fiscal years beginning after December 15, 2027. Early adoption is permitted. The Company is currently evaluating the impact of this standard on its consolidated financial statements and related disclosures.
In November 2024, the FASB issued ASU No. 2024-04, Debt with Conversion and Other Options (Subtopic 470-20): Induced Conversions of Convertible Debt Instruments (“ASU 2024-04”), which clarifies the assessment of whether certain settlements of convertible debt instruments should be accounted for as an inducement conversion or extinguishment of convertible debt. ASU 2024-04 is effective for annual periods
F-15
beginning after December 15, 2025 on either a prospective or retrospective basis and early adoption is permitted. The Company’s outstanding convertible debt matures in September 2025, prior to the Company’s planned adoption date. Therefore, the Company does not expect the adoption of this standard to have a material impact on its consolidated financial statements and related disclosures.
NOTE 3 — REVENUE AND GRANT INCOME RECOGNITION
The Company recognizes revenue under contracts with customers to provide nuclear reactor and fuel design engineering services in the areas of research and development, systems engineering, and technology development. The Company’s revenues are generally derived from contract services predominantly performed for the U.S. Government and commercial entities. All revenues for the years ended December 31, 2024 and 2023 were recognized over time.
There are two main types of contracts: cost-based contracts and cost plus fixed fee contracts. The total consideration in the Company’s contracts is paid in the form of incremental incurred cost reimbursements over time upon the delivery of the Company’s invoices.
The allowability of certain costs under government contracts is subject to audit by the government. Certain indirect costs are charged to contracts using provisional or estimated indirect rates, which are subject to later revision based on actual costs incurred and subject to government audits of those costs. The government has performed audits of the Company’s costs. Refer to Note 15 — Commitments and Contingencies, for further discussion of these cost audits.
Advanced Reactor Demonstrator Program
During the year ended December 31, 2021, the Company was named an awardee under the Department of Energy’s Advanced Reactor Demonstrator Program (“ARDP”). The objective of the ARDP is to accelerate the development and demonstration of advanced nuclear reactor technologies, focusing on designs that improve safety, efficiency, and economic viability for commercial deployment. Under the agreement, the Company will develop the Xe-100 demonstrator reactor and the TRISO-X commercial fuel fabrication facility through a public-private cost-share partnership. The DoE will obtain rights to the intellectual property (“IP”) developed under ARDP but will not obtain ownership of the demonstrator reactor or fuel facility. The DoE will fund a portion of the direct and indirect costs incurred for the research and development costs to develop the IP and the costs of developing and constructing both the TRISO-X fuel facility and Xe-100 demonstrator reactor. The program provides for a 50% reimbursement of up to $2.4 billion of eligible costs ($1.2 billion reimbursement) through 2027. The funding is subject to future government appropriations which may not occur, and the government is able to cancel the contract at any time without incurring a substantive penalty. Dow has been named a subawardee under the ARDP in connection with their involvement with the development and construction of the demonstrator reactor. The Company is constructing and will own the fuel facility.
The Company determined that the ARDP is partially in the scope of ASC 606 and partially in the scope of other guidance as the DoE only receives benefit from the development of the IP and does not receive benefit from construction of the demonstrator reactor or the fuel facility. The Company has allocated consideration between revenue and grant components of the ARDP on the basis of the stand-alone selling price of each of the components. The Company has analogized to IAS 20 to account for the component of the ARDP that is not within the scope of ASC 606 and deemed to be a government grant. The grant components consist of an asset grant and an income grant. The Company recognizes grants under ARDP as the Company incurs the eligible costs. Refer to Note 2 — Summary of Significant Accounting Policies and Recent Accounting Pronouncements and Note 5 — Government Grants for Property and Equipment.
Under the Company’s separate agreement with Dow, certain costs incurred by Dow related to the demonstrator reactor are funded by the Company using funds obtained through the ARDP. The Company has recognized the funds received from the DoE and the costs incurred by Dow on a gross basis as grant income and direct costs, respectively. The Company has recognized $5.6 million and zero as grant income and $4.6 million and zero as direct costs during the years ended December 31, 2024 and 2023, respectively related to costs incurred by Dow for the demonstrator reactor. The Company also earns revenue from Dow as a customer for certain site specific engineering, permitting, and other services related to the demonstrator reactor. Refer to Note 14 — Related Party Transactions.
F-16
Disaggregated Revenues and Grant Income
A summary of revenues and grant income by customer type is as follows for the years ended December 31 (in thousands):
| | | |
Year Ended December 31,
|
| |||||||||
| | | |
2024
|
| |
2023
|
| ||||||
| Customer Type: | | | | | | | | | | | | | |
| DoE(1) | | | | $ | 78,029 | | | | | $ | 122,726 | | |
|
DoD
|
| | | | 10,705 | | | | | | 2,612 | | |
|
Commercial
|
| | | | 31,418 | | | | | | 7,704 | | |
|
Total Revenues and Grant Income
|
| | | $ | 120,152 | | | | | $ | 133,042 | | |
(1)
For the year ended December 31, 2024, of the $78.0 million total revenues and grant income from the DoE, $41.8 million is classified as services revenue and $36.2 million is classified as grant income. For the year ended December 31, 2023, of the $122.7 million total revenues and grant income from the DoE, $111.5 million is classified as services revenue and $11.2 million is classified as grant income.
A summary of revenues and grant income by contract type is as follows for the years ended December 31 (in thousands):
| | | |
Year Ended December 31,
|
| |||||||||
| | | |
2024
|
| |
2023
|
| ||||||
| Contract Type: | | | | | | | | | | | | | |
| Cost-based(1) | | | | $ | 104,876 | | | | | $ | 130,113 | | |
|
Fixed Fee
|
| | | | 2,674 | | | | | | 1,838 | | |
|
Cost plus Fixed Fee
|
| | | | 11,954 | | | | | | — | | |
|
Time & Materials
|
| | | | 648 | | | | | | 1,091 | | |
|
Total Revenues and Grant Income
|
| | | $ | 120,152 | | | | | $ | 133,042 | | |
(1)
For the year ended December 31, 2024, of the $104.9 million total revenues and grant income from cost-based contracts, $68.7 million is classified as services revenue and $36.2 million is classified as grant income. For the year ended December 31, 2023, of the $130.1 million total revenues and grant income from cost-based contracts, $118.9 million is classified as services revenue and $11.2 million is classified as grant income.
Revenues and Grant Income by Geographic Location
The Company has revenues and grant income in the following countries for the years ended December 31 (in thousands):
| | | |
Year Ended December 31,
|
| |||||||||
| | | |
2024
|
| |
2023
|
| ||||||
| Customer Location: | | | | | | | | | | | | | |
|
United States
|
| | | $ | 118,803 | | | | | $ | 133,020 | | |
| Non-U.S.: | | | | | | | | | | | | | |
|
Canada
|
| | | | 645 | | | | | | 22 | | |
|
United Kingdom
|
| | | | 704 | | | | | | — | | |
|
Total Non-U.S.
|
| | | | 1,349 | | | | | | 22 | | |
|
Total Revenues and Grant Income
|
| | | $ | 120,152 | | | | | $ | 133,042 | | |
F-17
Contract Balances
The timing of revenue recognition, billings, and cash collections results in billed accounts receivable, unbilled receivables (including amounts billable where the right to consideration is unconditional and contract assets for which government approval is required before billing can occur), and contract liabilities (customer advances and deposits) on the consolidated balance sheets. Amounts are billed as work progresses in accordance with agreed-upon contractual terms, either at periodic intervals (e.g., biweekly or monthly) or upon achievement of contractual milestones. Generally, billing occurs subsequent to revenue recognition, resulting in unbilled receivables. However, the Company sometimes receives advances or deposits from its customers, before revenue is recognized, resulting in contract liabilities. These liabilities are reported on the consolidated balance sheets on a contract-by-contract basis at the end of each reporting period.
Contract liabilities as of December 31, 2024 and 2023 include deferred revenue. As of December 31, 2024, the Company has deferred revenue of $1.1 million, of which $0.3 million is recorded within accrued liabilities and $0.8 million is recorded within due to related parties. Deferred revenue was immaterial as of December 31, 2023.
Contract assets represent revenue recognized that exceeds the amount billed to the customer and excludes amounts billable where the right to consideration is solely subject to the passage of time. As of December 31, 2024, the Company has contract assets of $9.5 million, of which $1.9 million is recorded within due from related parties. Contract assets were immaterial as of December 31, 2023. The increase in contract assets during 2024 is due to rate variances that are billable upon negotiation of final indirect rates with the government.
Remaining Performance Obligation
Remaining performance obligations represent non-cancelable contracted revenue that has not yet been recognized and will be recognized as revenue in future periods. The Company has elected to apply the exemption for the disclosure of remaining performance obligations as the Company’s contracts are one year or less in duration.
NOTE 4 — PROPERTY AND EQUIPMENT, NET
Property and equipment, net consists of the following (in thousands):
| | | |
December 31,
2024 |
| |
December 31,
2023 |
| ||||||
|
Equipment and materials
|
| | | $ | 2,335 | | | | | $ | 2,335 | | |
|
Computer equipment and software
|
| | | | 1,131 | | | | | | 1,026 | | |
|
Office furniture and fixtures
|
| | | | 302 | | | | | | 303 | | |
|
Leasehold improvements
|
| | | | 2,480 | | | | | | 634 | | |
|
Land
|
| | | | — | | | | | | — | | |
|
Construction-in-progress
|
| | | | 1,778 | | | | | | 1,054 | | |
|
Property and equipment at cost
|
| | | | 8,026 | | | | | | 5,352 | | |
|
Less: accumulated depreciation
|
| | | | (2,198) | | | | | | (1,285) | | |
|
Property and equipment, net
|
| | | $ | 5,828 | | | | | $ | 4,067 | | |
All of the Company’s property and equipment is located within the United States.
During the year ended December 31, 2023, the Company recorded an immaterial correction within the period related to an understatement of property and equipment, net.
F-18
NOTE 5 — GOVERNMENT GRANTS FOR PROPERTY AND EQUIPMENT
In June 2022, one of the Company’s wholly owned subsidiaries was selected to receive a grant of land from the Industrial Development Board of the City of Oak Ridge, Tennessee (“City of Oak Ridge”). As part of the grant, the Company is required to invest at least $10.0 million toward the design, license, permit, power, construction, outfitting, and operation of a nuclear fuel fabrication facility on the parcel of land granted from the City of Oak Ridge. The Company has recorded the fair value of the land of $2.8 million and an offsetting reduction to the basis in the land in the same amount within property and equipment, net on the consolidated balance sheets.
During the year ended December 31, 2024, the Company received reimbursements from the DoE under the ARDP related to construction of its nuclear fuel fabrication facility. The Company recognizes the grant from the DoE at the time in which the costs of construction are incurred in compliance with the conditions of the grant, which were $7.7 million in 2024.
NOTE 6 — ACCRUED LIABILITIES
The following table sets forth the components of accrued liabilities (in thousands):
| | | |
December 31,
2024 |
| |
December 31,
2023 |
| ||||||
|
Operating lease liabilities
|
| | | $ | 2,486 | | | | | $ | 1,402 | | |
|
Accrued payroll and related expenses
|
| | | | 13,336 | | | | | | 8,314 | | |
|
Accrued subcontractor costs
|
| | | | 17,331 | | | | | | 13,143 | | |
|
Accrued terminated SPAC transaction costs
|
| | | | — | | | | | | 19,167 | | |
|
Accrued financing costs
|
| | | | 354 | | | | | | 1,125 | | |
|
Deferred revenue
|
| | | | 306 | | | | | | — | | |
|
Accrued liabilities – other
|
| | | | 1,566 | | | | | | 1,285 | | |
|
Total accrued liabilities
|
| | | $ | 35,379 | | | | | $ | 44,436 | | |
During the year ended December 31, 2023, the Company recorded an immaterial correction within the period related to an overstatement of accrued liabilities.
NOTE 7 — DEBT
The following table summarizes the Company’s outstanding debt (in thousands):
| | | |
December 31,
2024 |
| |
December 31,
2023 |
| ||||||
|
Live Oak Credit Facility
|
| | | $ | — | | | | | $ | 9,388 | | |
|
2023 Bridge Loan
|
| | | | — | | | | | | 21,279 | | |
|
C-1 Notes
|
| | | | — | | | | | | 25,901 | | |
|
C-2 Notes
|
| | | | 18,537 | | | | | | 121,240 | | |
|
Total
|
| | | | 18,537 | | | | | | 177,808 | | |
|
Less: short-term borrowings
|
| | | | (18,537) | | | | | | (56,568) | | |
|
Total long-term obligations
|
| | | $ | — | | | | | $ | 121,240 | | |
The fair value of the C-2 Notes outstanding as of December 31, 2024 and 2023 and the C-1 Notes outstanding as of December 31, 2023 equates to carrying value as the Company elected to apply the fair value option to the measurement of the C-1 Notes and C-2 Notes. The fair value of the Live Oak Credit Facility and 2023 Bridge Loan as of December 31, 2023 approximates carrying value due to the variable market interest rate and the short time span between issuance and the balance sheet date, respectively.
Live Oak Credit Facility
On June 14, 2021, the Company and one of the Company’s subsidiaries entered into a credit agreement for a revolving credit facility (the “Live Oak Credit Facility”) with Live Oak Bank. The Live Oak Credit
F-19
Facility provided for maximum borrowings of up to $15.0 million, subject to an asset-based borrowing base. The borrowing base was limited to a set percentage of eligible accounts, less reserves that may be established by the lender in the exercise of their reasonable credit judgment. Subject to certain conditions, the Live Oak Credit Facility, as amended prior to 2024, was set to expire on April 30, 2024, which was extended to October 31, 2024 through amendments entered into during 2024. In connection with the credit agreement, the Company incurred lender and third-party fees. Additionally, a commitment fee was accrued on any unused portion of the commitments under the Live Oak Credit Facility during the preceding three calendar month period. The commitment fee was 0.25% applied to the difference between the revolving commitment and the average daily outstanding balance for each quarter. The lender and third-party fees and commitment fees were immaterial for the years ended December 31, 2024 and 2023.
The obligations under the Live Oak Credit Facility were guaranteed by the Company and its wholly owned domestic subsidiaries. The obligations under the Live Oak Credit Facility were secured by a first priority security interest in substantially all of the equipment, accounts receivable, investment property and general intangibles and all proceeds and products thereof, as well as 100% of the common equity interests of the present and subsequently acquired domestic subsidiaries of the Company. The Live Oak Credit Facility was permitted to be voluntarily prepaid in whole, or in part, in each case without premium or penalty. The Company was also required to make mandatory prepayments when (a) the aggregate borrowings exceed the lesser of the (i) revolving commitment and (ii) the available borrowing base or (b) certain events of default have occurred and were continuing.
The Live Oak Credit Facility carried an interest rate based on a floating rate indexed to the Prime rate plus 1.0%, subject to a 4% floor. The average interest rate in effect under the Live Oak Credit Facility was 9.5% and 9.13% for the years ended December 31, 2024 and 2023, respectively. Interest expense associated with this credit facility for the years ended December 31, 2024 and 2023 was $0.4 million and $0.8 million, respectively.
In accordance with the Live Oak Credit Facility’s stated terms, the Company settled the outstanding principal associated with the Live Oak Credit Facility in October 2024. On October 31, 2024, with no outstanding borrowings, the facility matured. As of December 31, 2023, the outstanding balance was $9.4 million, and the unused capacity was $5.6 million.
Series C-1 Convertible Notes
In 2022, the Company issued a series of convertible promissory notes (“C-1 Notes”) in the aggregate principal amount of $57.4 million with an annual interest rate of 7.00%. Of the $57.4 million in principal, $37.4 million was due on March 31, 2024 and $20.0 million was due on October 7, 2024 to a related party.
While the C-1 Notes were outstanding, in the event that the Company issued and sold units of its preferred equity securities (the “Equity Securities”) to investors on or before the maturity date in an equity financing with total proceeds to the Company not less than a) $50.0 million for the $37.4 million principal amount due March 31, 2024, or b) $150.0 million for the $20.0 million principal amount due October 7, 2024 (a “Qualified Financing”), then the outstanding principal amount of the C-1 Notes and any unpaid accrued interest would automatically convert into Equity Securities sold in the Qualified Financing at a conversion price equal to the lesser of (i) 90% of the price paid per unit for Equity Securities by the respective investors and (ii) the quotient resulting from dividing $1.5 billion by the number of outstanding security interests for the Company immediately prior to the equity financing (assuming conversion of all securities convertible into Class A Common Units). Upon such automatic conversion, the Company was permitted to elect to convert the C-1 Notes into units of a newly created series of preferred units with identical rights, privileges, preferences and restrictions as the Equity Securities sold in the Qualified Financing, other than with respect to the per unit liquidation preference, the conversion price for purposes of price-based anti- dilution protection, and the per unit dividend.
In the event of a deemed liquidation event while these notes remained outstanding, the Company would have been required to repay the investors in cash in an amount equal to the outstanding principal amount of the C-1 Notes plus any unpaid accrued interest on the original principal, provided that the holder was permitted to convert the outstanding principal balance of the C-1 Notes and any unpaid accrued interest into units of the Company’s Class A Common Units at a conversion price equal to the quotient resulting from
F-20
dividing $1.5 billion by the number of outstanding units of equity interests of the Company immediately prior to the deemed liquidation event (assuming conversion of all securities convertible into Class A Common Units).
The C-1 Notes contained embedded derivatives which, absent the election of the fair value option, would have been bifurcated and accounted for at fair value. Accordingly, the fair value option was elected. The Company classified the C-1 Notes as a liability at fair value and remeasured the C-1 Notes to their fair value at each reporting period, with the portion of the change in fair value attributable to instrument- specific credit risk recorded within other comprehensive income (loss), and the remaining change in fair value recorded within other expense, net. As the fair value option was elected, issuance costs associated with the C-1 Notes were expensed in the period incurred. Refer to Note 13 — Fair Value Measurements for further information on the remeasurement of the C-1 Notes.
In connection with the October 2022 issuance of the $20.0 million C-1 Notes due October 7, 2024, the Company issued warrants (the “October 2022 Warrants”) to purchase Series C Preferred Units for a strike price of $0.01. The October 2022 Warrants were deemed to be freestanding financial instruments and were classified as a liability as they represent the obligation to issue units that are redeemable for cash upon the occurrence of certain events that are considered outside of the Company’s control. During the year ended December 31, 2024, in conjunction with the C-1 Conversion (defined below), the October 2022 Warrants were exercised in exchange for 582,094 Series C Preferred Units.
On December 5, 2023, in connection with the issuance of the Series C Preferred Units, a portion of the C-1 Notes equal to $37.4 million of principal automatically converted into 5,957,402 Series C Preferred Units at a discounted price per unit of $7.94.
As of December 31, 2023, the outstanding principal on the C-1 Notes was $20.0 million and the fair value was $25.9 million, resulting in a cumulative loss of $5.9 million.
On March 29, 2024, the remaining $20.0 million principal outstanding on the C-1 Notes converted into 3,210,405 Series C Preferred Units (the “C-1 Conversion”). To facilitate the conversion, a related party investor entered into an agreement which required a payment of cash or equity to the former holder of such C-1 Notes if certain conditions related to a future financing by the Company were not met. In conjunction with the C-1 Conversion, on March 29, 2024, the Company entered into a Letter Agreement with the related party investor pursuant to which the Company would reimburse the investor for any future cash or equity payments (such obligation to reimburse, the “2024 Financial Instrument”), which could have become due and payable to the former holder of the C-1 Notes from the related party investor. The 2024 Financial Instrument is accounted for as a liability pursuant to Accounting Standards Codification (“ASC”) 480-10, Distinguishing Liabilities from Equity (“ASC 480-10”), because it is indexed to an obligation to repurchase the Company’s equity shares and may require the Company to transfer assets to the related party investor. Additionally, pursuant to the measurement guidance provided by ASC 480-10, the 2024 Financial Instrument was initially measured at fair value and remeasured to fair value on a periodic basis with any changes in fair value recognized in earnings. Refer to Note 13 — Fair Value Measurements for further information on the remeasurement of the 2024 Financial Instrument. Additionally, under the terms of the Letter Agreement, the Company issued 757,135 Class B Common Units on March 29, 2024, which have the same rights and obligations as the Class B-1 Profits Interests discussed in Note 12 — Unit-Based Compensation Expense. The Class B Common Units were recorded in the mezzanine equity section of the consolidated balance sheet.
The C-1 Conversion was accounted for as an induced conversion in accordance with ASC 470-20, Debt with Conversion and Other Options. The induced conversion resulted in the recognition of an inducement expense of $14.8 million which was inclusive of the value of the issued Class B Common Units and the 2024 Financial Instrument, and presented in other expense, net in the consolidated statements of operations and comprehensive loss for the year ended December 31, 2024. Since the C-1 Notes were historically accounted for by applying the fair value option, in accordance with ASC 825-10, Financial Instruments — Overall (“ASC 825-10”), the Company included in net loss the $1.3 million cumulative gain previously recorded in other comprehensive income (loss) for the extinguished C-1 Notes that resulted from changes in instrument-specific credit risk.
F-21
Series C-2 Convertible Notes
In 2022 and 2023, the Company issued convertible notes payable in an aggregate principal amount of $28.0 million and $85.0 million (“C-2 Notes”), respectively, of which $70.0 million of the C-2 Notes were issued to related parties. The C-2 Notes were scheduled to mature on September 30, 2025 and accrue 10.0% of payable-in-kind interest annually.
In the event that the Company consummates an IPO on or before the maturity date, the holders may elect to convert the then outstanding principal amount of the C-2 Notes into equity securities sold in the IPO transaction at a conversion price equal to 90% of the price paid per share for equity securities by investors in the IPO transaction. Additionally, at any time after August 4, 2023 and before the maturity date, holders of the C-2 Notes have the right to elect to the convert the C-2 Notes into shares of newly created series of preferred equity securities of the Company, at a conversion price implied by the pre-money value of $1.8 billion. These preferred equity securities will have identical rights, privileges, preferences and restrictions as the C-2 Notes except for the per share liquidation preference, the conversion price for purposes of price based anti-dilution protection and the per share mandatory dividend. The newly created series of preferred equity securities will rank senior in liquidation, dividends, redemption and other rights and preferences to all other classes and series of equity securities currently existing or authorized thereafter. Upon the conversion of the C-2 Notes into capital interests, the Company will pay the investors cash equal to the amount of any fractional units, calculated as the fraction of units multiplied by the price at which the note converts.
The Series C-2 Convertible Notes contained embedded derivatives which, absent the election of the fair value option, would have been bifurcated and accounted for at fair value. Accordingly, the fair value option was elected. The Company classified the C-2 Notes as a liability at fair value and remeasured the C-2 Notes to their fair value at each reporting period, with the portion of the change in fair value attributable to instrument-specific credit risk recorded within other comprehensive income (loss), and the remaining change in fair value recorded within other income (expense), net. As the fair value option was elected, issuance costs associated with the C-2 Notes are expensed in the period incurred. Refer to Note 13 — Fair Value Measurements for further information on the remeasurement of the C-2 Notes.
On October 11, 2024, certain of the C-2 Notes with an aggregate principal balance of $98.0 million converted into 16,960,021 Series C Preferred Units, which was accounted for as a debt extinguishment. Such extinguishment resulted in a gain on debt extinguishment of $17.6 million for the year ended December 31, 2024, which was recorded in other income (expense), net in the consolidated statements of operations. Further, since the C-2 Notes were historically accounted for by applying the fair value option, in accordance with ASC 825-10, the Company included in net loss the $6.1 million cumulative loss previously recorded in other comprehensive income (loss) for the extinguished C-2 Notes that resulted from changes in instrument-specific credit risk.
As of December 31, 2024, the outstanding principal, inclusive of payable-in-kind interest, on the C-2 Notes was $18.4 million and the fair value was $18.5 million, resulting in a cumulative loss of $0.1 million.
As of December 31, 2023, the outstanding principal, inclusive of payable-in-kind interest, on the C-2 Notes was $121.8 million and the fair value was $121.2 million, resulting in a cumulative gain of $0.6 million.
2023 Bridge Loan
On October 4, 2023, the Company entered into a credit agreement (the “2023 Bridge Loan”) with a related party, Ares Acquisition Holdings, LP for a $10.0 million term loan. In addition, subject to the mutual agreement of Ares Acquisition Holdings, LP, additional draws of up to $10.0 million per calendar month were available to the Company from October 31, 2023 until the earliest of (i) February 7, 2024, (ii) the date on which the entire amount of $40.0 million has been drawn or reduced to zero and (iii) termination under an event of default, so long as the conditions of the 2023 Bridge Loan have been satisfied.
The annual interest rate on the 2023 Bridge Loan was 12.0%. For the years ended December 31, 2024 and 2023, interest expense of $3.0 million and $0.4 million, respectively, associated with the 2023 Bridge Loan was recorded within interest expense on the consolidated statements of operations. The interest is payable in-kind and increases the outstanding principal amount of the 2023 Bridge Loan.
F-22
On December 5, 2023, the Company entered into an amendment to the 2023 Bridge Loan that extended the maturity date of the borrowings to April 30, 2024, and provided for the draw amount for the calendar month of December 2023 to increase to $14.2 million, which was drawn by the Company on December 5, 2023. The Company concluded the extension of the maturity date constituted a troubled debt restructuring. As the undiscounted cash flows of the restructured loan were greater than the carrying amount of the loan immediately prior to restructuring, no restructuring gain was recognized. The Company immediately expensed all third-party transaction costs associated with the restructuring.
During 2024, the Company entered into a series of amendments to the 2023 Bridge Loan, which, among other things, extended the maturity date to March 26, 2025. The Company concluded that each of the amendments to the 2023 Bridge Loan constituted, for accounting purposes, debt extinguishments and recognized debt extinguishment losses of $6.8 million. The Company drew a total of $25.8 million on the 2023 Bridge Loan during 2024, including draws made in conjunction with amendments. In conjunction with the draws, the Company issued 1.7 million Class B Common Units to Ares Acquisition Holdings, LP. The Class B Common Units have the same rights as the Class B Profits Interests discussed in Note 12 — Unit-Based Compensation Expense. The Class B Common Units were recorded in the mezzanine equity section of the consolidated balance sheets either at fair value, for Class B Common Units issued in conjunction with the debt extinguishments, or at relative fair value, for Class B Common Units issued in conjunction with a draw.
On October 11, 2024, in accordance with the 2023 Bridge Loan’s stated terms, the Company paid the outstanding principal and interest on the 2023 Bridge Loan of $53.5 million, and the 2023 Bridge Loan was settled. The settlement has been accounted for as an extinguishment of the 2023 Bridge Loan. As a result, the Company recorded a loss on debt extinguishment of $0.1 million for the year ended December 31, 2024 in other income (expense), net in the consolidated statements of operations and no balance was outstanding at December 31, 2024.
The Company assessed the terms of the 2023 Bridge Loan in order to identify embedded features and determine if any such features should be bifurcated and accounted for separately as derivative. The Company determined that the event of default interest rate adjustment feature, event of default redemption feature, and contingent additional interest feature required bifurcation and separate accounting as derivative liabilities. Accordingly, the bifurcated embedded derivatives were recorded at fair value upon issuance of each relevant draw and were subsequently remeasured at the end of each reporting period. The bifurcated embedded derivatives that were created upon new draws resulted in a discount on the 2023 Bridge Loan which was subsequently amortized over the life of the 2023 Bridge Loan through periodic charges to interest expense.
During the years ended December 31, 2024 and 2023, the Company recorded $4.2 million and $0.7 million, respectively, in interest expense related to the amortization of the discount created by embedded derivatives. Additionally, the new embedded derivatives, with a total fair value of $2.7 million, were recorded as a part of the amendments and included in the loss on extinguishment. The Company determined the fair value of the embedded derivatives by considering the probability of the settlement of the feature, its settlement value, and other assumptions. See Note 13 — Fair Value Measurements for further information.
2024 Convertible Note
On September 26, 2024, the Company entered into a convertible note with Amazon.com NV Investment Holdings LLC in the principal amount of $20.0 million (the “2024 Convertible Note”). While outstanding, the debt accrued paid-in-kind interest of 12% per annum, compounded quarterly. Interest expense recognized related to the 2024 Convertible Note was immaterial during the year ended December 31, 2024. The 2024 Convertible Note was convertible at the option of the creditor into Series C-1 Preferred Units from the issuance date until the occurrence of a Qualified Financing, which is defined under the 2024 Convertible Note’s terms as the Company’s completion of a financing round of Series C-1 Preferred Units with total proceeds of at least $100.0 million on or before the maturity date. The maturity date of the 2024 Convertible Note was March 26, 2025, or upon the receipt of a third-party investment with aggregate net cash proceeds of at least $100.0 million, if such an investment occurs prior to the maturity date.
On October 11, 2024, in conjunction with the Series C-1 Preferred Units financing discussed below and in accordance with the 2024 Convertible Note’s stated terms, the outstanding principal and interest of the 2024 Convertible Note of $20.1 million was converted into 3,097,477 Series C-1 Preferred Units (“2024 Convertible
F-23
Note Conversion”). Since the 2024 Convertible Note was converted via the creditor’s exercise of its unit-settled redemption right, the conversion was accounted for as a debt extinguishment and no balance remained outstanding at December 31, 2024. The fair value of the Series C-1 Preferred Units approximated the value of the extinguished debt plus interest, and therefore, no gain or loss was recorded during the year ended December 31, 2024.
2024 Bridge Loan
On September 26, 2024, the Company entered into a bridge loan with Escape2, LLC, an entity affiliated with an investor (the “2024 Bridge Loan”), in the amount of $3.8 million. While outstanding, the 2024 Bridge Loan accrued paid-in-kind interest of 12% per annum, compounded quarterly and had a maturity date of March 26, 2025, or upon the receipt of a third-party investment with aggregate net cash proceeds of at least $100.0 million, if such an investment occurs prior to the maturity date. Concurrently with the issuance of this debt, the Company issued 124,430 Class B Common Units to Ghaffarian Enterprises, LLC, which is controlled by the same related party investor as Escape 2, LLC. The Class B Common Units have the same rights as the Class B Profits Interests discussed in Note 12 — Unit- Based Compensation Expense. The Class B Common Units were recorded in the mezzanine equity section of the consolidated balance sheets and included in the discount of the 2024 Bridge Loan.
On October 11, 2024, in accordance with its stated terms, the 2024 Bridge Loan was automatically redeemed, and the Company paid the outstanding principal and interest associated with the 2024 Bridge Loan of $3.8 million. Since the 2024 Bridge Loan was initially recognized at its relative fair value (as a result of the concurrent issuance of the Class B Common Units to Ghaffarian Enterprises, LLC), its carrying amount at settlement was not equal to the cash paid by the Company. As a result, the debt was removed at its carrying value, the cash payment was credited, and a loss on extinguishment was recorded for the difference. The Company recorded an immaterial loss on debt extinguishment during the year ended December 31, 2024 in other income (expense), net in the consolidated statements of operations and no balance remained outstanding at December 31, 2024.
Bank of New York Credit Facility
On July 28, 2020, the Company executed a credit agreement with Pershing LLC, an affiliate of Bank of New York Mellon, in the form of a revolving credit facility (the “Bank of New York Credit Facility”), which was subject to the guarantee by Ghaffarian Enterprises, LLC and Ghaffarian Enterprises, who represented related party investors.
On December 2, 2023, the Company and Ghaffarian Enterprises entered into a Letter Agreement which stipulated Ghaffarian Enterprises would purchase $29.3 million of Series C Preferred Units and the proceeds were used to fully repay the Bank of New York Credit Facility, at which time the outstanding balance was approximately $31.0 million. In conjunction with the Company’s repayment of the outstanding balance, the collateral posted by Ghaffarian Enterprises was released and the reimbursement agreement and guaranty with Ghaffarian Enterprises terminated in December 2023.
During the year ended December 31, 2024, the Company entered into Credit Support Fee and Subrogation Agreements (the “2024 Credit Support Fee Agreements”) with GM Enterprises LLC and Ghaffarian Enterprises, LLC, entities affiliated with an investor, which increased the availability under the Bank of New York Credit Facility to $20.0 million and extended the maturity of the credit support to March 26, 2025. In conjunction with the 2024 Credit Support Fee Agreements, the Company agreed to pay GM Enterprises, LLC and Ghaffarian Enterprises, LLC a monthly 12% credit support fee to be paid in- kind. Pursuant to the terms of the 2024 Credit Support Fee Agreements, the Company paid credit support fees and issued 562,483 Class B Common Units to GM Enterprises LLC and Ghaffarian Enterprises, LLC. See Note 14 — Related Party Transactions for further information on the credit support fee. The Class B Common Units have the same rights as the Class B Profits Interests discussed in Note 12 — Unit-Based Compensation Expense. The Class B Common Units were recorded in the mezzanine equity section of the consolidated balance sheets and included in the discount of the Bank of New York Credit Facility.
On October 11, 2024, in accordance with the facility’s stated terms, the Company settled the outstanding principal and interest associated with the Bank of New York Credit Facility with a payment of $20.2 million,
F-24
and the 2024 Credit Support Fee Agreements were terminated. The Bank of New York Credit Facility did not have an outstanding balance as of December 31, 2024 or 2023.
Borrowings under the Bank of New York Credit Facility bear interest at the Federal Funds rate, subject to a 0.25% floor, plus a margin. For borrowings, the applicable rate margin is 0.90%. The proceeds of loans under the agreement are available for working capital needs, permitted acquisitions and other general corporate purposes. The average interest rate in effect under the Bank of New York Credit Facility was 6.34% and 6.32% for the years ended December 31, 2024 and 2023, respectively. For the years ended December 31, 2024 and 2023, interest expense associated with the Bank of New York Credit Facility was $0.5 million and $1.8 million, respectively.
NOTE 8 — LEASES
Lease balances as of December 31, 2024 and 2023 are as follows (in thousands):
| | | |
December 31,
2024 |
| |
December 31,
2023 |
| ||||||
|
Operating lease ROU assets
|
| | | $ | 11,003 | | | | | $ | 12,188 | | |
|
Current portion of operating lease liabilities
|
| | | | 2,486 | | | | | | 1,402 | | |
|
Long-term portion of operating lease liabilities
|
| | | | 10,338 | | | | | | 11,674 | | |
|
Total operating lease liabilities
|
| | | $ | 12,824 | | | | | $ | 13,076 | | |
The current portion of operating lease liabilities is reflected within accrued liabilities on the consolidated balance sheets.
Operating Leases
The Company leases office spaces, which have initial operating lease terms of three to eight years. Some leases have options to extend the lease term, ranging from six months to six years. Certain leases have early termination options, which the Company is not reasonably certain to exercise.
During 2023, the Company entered into new operating leases for additional office space, with terms ranging from approximately three to five years, and also modified certain existing leases to extend the lease term approximately five years. During 2024, the Company modified certain existing leases to extend lease terms, with increases ranging from approximately six months to two years.
Operating lease cost totaled $4.4 million and $4.6 million for the years ended December 31, 2024 and 2023, respectively, and was recognized on a straight-line basis over the lease term. Variable lease expenses and short-term lease expenses were immaterial for the years ended December 31, 2024 and 2023.
Future minimum lease payments under operating leases as of December 31, 2024 are as follows (in thousands):
| | | |
Operating
Leases |
| |||
|
2025
|
| | | | 3,636 | | |
|
2026
|
| | | | 2,988 | | |
|
2027
|
| | | | 2,848 | | |
|
2028
|
| | | | 2,789 | | |
|
2029
|
| | | | 2,842 | | |
|
Thereafter
|
| | | | 1,238 | | |
|
Total minimum lease payments
|
| | | | 16,341 | | |
|
Less: amounts representing interest or imputed interest
|
| | | | (3,517) | | |
|
Present value of lease obligations
|
| | | $ | 12,824 | | |
F-25
Supplemental cash flow information relating to the Company’s leases is as follows (in thousands):
| | | |
December 31,
|
| |||||||||
| | | |
2024
|
| |
2023
|
| ||||||
|
Operating cash flows used in operating leases
|
| | | $ | 2,756 | | | | | $ | 3,778 | | |
| Non-Cash Items: | | | | | | | | | | | | | |
|
Change to ROU asset and lease liability due to lease modifications and reassessments
|
| | | | 1,450 | | | | | | 1,040 | | |
|
ROU assets recorded under new operating leases
|
| | | | — | | | | | | 9,604 | | |
The weighted average remaining lease term and discount rates for operating leases are as follows:
| | | |
Year Ended
December 31, |
| |||
| | | |
2024
|
| |
2023
|
|
|
Weighted Average Remaining Lease Term
|
| |
5.0 years
|
| |
5.3 years
|
|
|
Weighted Average Discount Rate
|
| |
10.0%
|
| |
10.0%
|
|
NOTE 9 — PROFIT SHARING PLAN
The Company maintains a defined contribution profit sharing plan (the “Plan”), which includes a salary deferral arrangement, under the provisions of Section 401(k) of the Internal Revenue Code. Employees are eligible to participate in the Plan on the date of employment. Employees may contribute up to 100% of annual compensation limited to Internal Revenue Code Service maximums. The Company matches 100% of employees’ contributions up to 4% of annual compensation. The Company contributed $3.0 million and $3.1 million to the Plan during the years ended December 31, 2024 and 2023, respectively.
NOTE 10 — INCOME TAX
X-energy is a limited liability company which is classified as a partnership for U.S. federal and state income tax purposes. Accordingly, the Company’s U.S. operations are not subject to income taxes in the U.S. The Company’s owners separately account for their pro rata share of the Company’s income, deductions, losses and credits annually. The Company’s foreign operations are subject to income taxes in the foreign jurisdictions in which they operate.
The following table sets forth the components of income (loss) before income taxes recognized on the consolidated statements of operations and comprehensive loss (in thousands):
| | | |
Year Ended December 31,
|
| |||||||||
| | | |
2024
|
| |
2023
|
| ||||||
|
U.S.
|
| | | $ | (109,042) | | | | | $ | (228,535) | | |
|
Foreign
|
| | | | (16,918) | | | | | | (2,685) | | |
| Total | | | | $ | (125,960) | | | | | $ | (231,220) | | |
No income tax (expense) benefit was recorded for the years ended December 31, 2024 and 2023.
F-26
A reconciliation of income taxes computed at the U.S. federal statutory income tax rate of 21% to the Company’s income tax (expense) benefit was as follows:
| | | |
December 31,
2024 |
| |
December 31,
2023 |
| ||||||
|
U.S. Federal Statutory Tax Rate
|
| | | | 21.0% | | | | | | 21.0% | | |
|
Domestic Income Not Subject to Income Tax
|
| | | | (18.2)% | | | | | | (20.8)% | | |
|
Foreign Rate Differential
|
| | | | 0.0% | | | | | | 0.1% | | |
|
Prior Year Adjustments
|
| | | | (1.4)% | | | | | | 0.0% | | |
|
Other
|
| | | | 0.3% | | | | | | 0.0% | | |
|
Valuation Allowance
|
| | | | (1.7)% | | | | | | (0.3)% | | |
| | | | | | 0.0% | | | | | | 0.0% | | |
The Company’s effective tax rate for the years ended December 31, 2024 and 2023 was 0.0%.
The components of deferred tax assets and liabilities are as follows (in thousands):
| | | |
December 31,
|
| |||||||||
| | | |
2024
|
| |
2023
|
| ||||||
| Deferred Tax Assets: | | | | | | | | | | | | | |
|
Property and Equipment
|
| | | $ | 2 | | | | | $ | 2 | | |
|
Net Operating Losses
|
| | | | 3,866 | | | | | | 1,904 | | |
|
Total Deferred Tax Assets
|
| | | | 3,868 | | | | | | 1,906 | | |
|
Valuation Allowance
|
| | | | (3,853) | | | | | | (1,890) | | |
|
Total Deferred Tax Assets Net of Valuation Allowance
|
| | | | 15 | | | | | | 16 | | |
| Deferred Tax Liabilities: | | | | | | | | | | | | | |
|
Foreign Exchange
|
| | | | (15) | | | | | | (16) | | |
|
Total Deferred Tax Liabilities
|
| | | | (15) | | | | | | (16) | | |
|
Net Deferred Tax Assets/(Liabilities)
|
| | | $ | — | | | | | $ | — | | |
The Company’s net deferred tax assets are comprised primarily of net operating loss carryforwards. The ultimate realization of the net deferred tax assets is dependent upon the generation of future taxable income sufficient to utilize the deferred tax assets on the Company’s income tax returns. The Company determined that its net deferred tax assets are not more likely than not going to be realized due to the Company’s three-year cumulative loss position and the generation of future taxable income is uncertain. We are subject to taxation in the United States and various foreign jurisdictions. Tax years 2022 and forward are open for examination in the United States, tax years 2023 and forward are open for examination in the United Kingdom, and all years are open in Canada. Considering this and other factors, the Company recognized a full valuation allowance of $3.9 million and $1.9 million as of December 31, 2024 and 2023, respectively. The valuation allowance increased by $2.1 million during the year ended December 31, 2024 and increased by $0.7 during the year ended December 31, 2023.
As of December 31, 2024 and 2023, the Company had unused Canadian net operating losses of $7.3 million and $7.2 million, respectively, which begin to expire in 2040. As of December 31, 2024 and 2023, the Company had unused United Kingdom net operating losses of $7.7 million and zero, respectively, which can be carried forward indefinitely.
The Company had no liability for uncertain tax positions and had no interest or penalties with respect to unrecognized tax benefits as of December 31, 2024 and 2023.
F-27
NOTE 11 — MEMBER UNITS AND PREFERRED UNITS
The designations and the powers, privileges and rights, and the qualifications, limitations or restrictions thereof in respect to each of the Company’s class of capital units are set forth below.
Common Units
The holders of Class A Common Units are entitled to one vote for each unit of Class A Common Units held at all meetings of stockholders. The voting, dividend, and liquidation rights of the holders of Class A Common Units are subject to and qualified by the rights, powers and privileges of the holders of Preferred Units set forth in the original or amended Certificate of Incorporation. The Class A Common Units have been classified as mezzanine equity as they are redeemable for cash upon the occurrence of certain events that are considered outside of the Company’s control.
The Class B Common Units have the same rights and preferences as the Class A Common Units; provided however, the Class B Common Units shall not have voting rights and are subject to a profits interest threshold as may be set forth in grant agreements under the Company’s unit-based compensation plan discussed in Note 12 — Unit-Based Compensation Expense or certain credit agreements discussed in Note 7 — Debt.
During the year ended December 31, 2023, the Company issued 5,421,068 Class B-2 Common Units together with the Series C Preferred Units and Series A-1 Preferred Units in exchange for a cash investment of $50.0 million. The Company completed a relative fair value allocation of which $6.8 million was attributed to the Common Class B-2 Units. During the year ended December 31, 2024, the Company issued 3,126,887 Class B-2 Common Units in conjunction with the issuance and modification of debt and in conjunction with the conversion of the C-1 Notes as discussed in Note 7 — Debt. The Class B-2 Common Units are classified as mezzanine equity as they are redeemable for cash upon the occurrence of certain events that are considered outside of the Company’s control.
Series A Preferred Units
The Series A Preferred Units were initially recognized at fair market value on the issuance date.
Series A-1 Preferred Units
During the year ended December 31, 2023, the Company issued 8,808,351 Series A-1 Preferred Units in conjunction with Class B-2 Common Units and Series C Preferred Units as part of a financing that resulted in a cash investment of $50.0 million. The Company allocated the cash proceeds received from this financing based on the relative fair values of the instruments issued. Accordingly, $21.5 million was attributed to the Series A-1 Preferred Units.
Series B Preferred Units
The Series B Preferred Units have been initially recognized at fair market value.
Series C Preferred Units
During the year ended December 31, 2023, the Company issued 16,340,900 Series C Preferred Units. Specifically, the following issuances of Series C Preferred Units occurred during the year ended December 31, 2023:
The Company issued 6,548,964 Series C Preferred Units in conjunction with the Common B-2 Units and Series A-1 Preferred Units as part of a financing that resulted in a cash investment of $50.0 million. As mentioned above, the Company allocated the cash proceeds received from this financing based on the relative fair values of the instruments issued. Accordingly, $21.7 million was attributed to the Series C Preferred Units.
Additionally, 3,834,534 Series C Preferred Units were issued to a related party in exchange for an investment of $29.3 million. Based on the fair value of the Series C Preferred Units, the Company recognized a loss of $1.2 million upon issuance during the year ended December 31, 2023.
F-28
Further, 5,957,402 Series C Preferred Units were issued in exchange for the conversion of certain outstanding C-1 Notes with an aggregate fair market value equal to $47.3 million.
During the year ended December 31, 2024, 20,752,520 Series C Preferred Units were issued in connection with the C-1 Conversion, the C-2 Note Conversion, and the exercise of the October 2022 Warrants. These Series C Preferred Units issued as a result of these transactions were recognized at fair market value. Refer to Note 7 — Debt for further discussion on these convertible note conversions and the warrant exercise.
Series C-1 Preferred Units
During 2024, the Company completed a financing round of Series C-1 Preferred Units which resulted in the receipt of gross cash proceeds of approximately $626.5 million from various investors. As a result of this financing round, the Company issued 99,672,593 Series C-1 Preferred Units. The Series C-1 Preferred Units issued through these transactions were recorded at fair value.
In connection with the issuance of the Series C-1 Preferred Units, one investor and potential future customer was issued a warrant on Series C-1 Preferred Units (the “2024 Warrant”) for no additional consideration. The 2024 Warrant is required to be classified as a liability and measured at fair value on an ongoing basis pursuant to ASC 480 since the underlying Series C-1 Preferred Units are redeemable for cash upon the occurrence of certain events that are considered outside of the Company’s control. The 2024 Warrant may be exercised by the holder at any time from the issuance date until the 18-month anniversary of the issuance date and entitles the holder to purchase up to 40,214,207 Series C-1 Preferred Units at an exercise price of approximately $7.46 per unit. As the 2024 Warrant was issued for no additional consideration and did not meet the criteria for capitalization of a contract asset, the issuance date fair value of the 2024 Warrant of $55.3 million was expensed upon its issuance. The expense is reflected within selling, general, and administrative expenses within the consolidated statement of operations for the year ended December 31, 2024.
Preferred Units
Together, the Series A Preferred Units, the Series A-1 Preferred Units, the Series B Preferred Units, the Series C Preferred Units, and the Series C-1 Preferred Units shall be referred to as the “Preferred Units” for the purpose of this Note. Preferred Units have been issued in one or more series, each of such series consisting of such number of units and to have such terms, rights, powers and preferences, and the qualifications and limitation with respect thereto, as stated or expressed in the original or amended Certificate of Incorporation. Specifics regarding the conversion features and voting rights associated with, and the balance sheet classification of, the Preferred Units outstanding are as follows:
Optional Conversion Feature
Each Preferred Unit is convertible, at the option of the holder thereof, at any time, and without the payment of additional consideration by the holder thereof, into an equal number of Class A Common Units as is determined by dividing the Original Issue Price, initially (i) $0.5754 per Unit for each Series A Preferred Unit, (ii) $7.6348 for each Series A-1 Preferred Unit, (iii) $9.1162 per Unit for each Series B Preferred Unit, (iv) $7.6348 per Unit for each Series C Preferred Unit, and (v) $6.487 per Unit for each Series C-1 Preferred Unit, for the series of preferred units by the conversion price, initially equal to the applicable original issue price per unit, of such series of Preferred Units in effect at the time of conversion. Outstanding Preferred Units are therefore convertible into the following quantities of Class A Common Units as of December 31, 2024: 90,625,588 relating to Series A Preferred Units, 8,808,351 relating to Series A-1 Preferred Units, 11,643,171 relating to Series B Preferred Units, 37,093,420 relating to Series C Preferred Units, and 99,672,593 relating to Series C-1 Preferred Units. Conversion may be effected at any time at the sole discretion of the holder.
Automatic Conversion Feature
In the event of (i) a Qualified IPO or (ii) the approval of the requisite holders, the Preferred Units will automatically be converted into an equal number of Class A Common Units at the applicable conversion ratio.
F-29
Voting Rights
Each of the holders of Class A Common Units, Series A Preferred Units, Series B Preferred Units, Series C Preferred Units, and Series C-1 Preferred Units are entitled to vote for members of the Board of Directors in whatever manner necessary to ensure that the size of the Board of Directors of the Company is set and remains at nine directors who serve as the managers of the Company. The Series A-1 Preferred Units do not vote on the Board of Directors.
Cumulative Preferred Return
The Preferred Units have an annual 3% cumulative preferred return on the original issuance price, beginning on the date such Preferred Units were issued. As of December 31, 2024, the accumulated preferred return not reflected in the consolidated balance sheet for Series A, A-1, B, C, and C-1 Preferred Units was $5.4 million, $2.2 million, $10.9 million, $5.5 million, and $3.5 million, respectively. As of December 31, 2023, the accumulated preferred return not reflected in the consolidated balance sheet for Series A, A-1, B, and C Preferred Units was $3.8 million, $0.1 million, $7.7 million, and $0.3 million, respectively. In the event of a deemed liquidation, the cumulative preferred return is payable solely for the Series B Preferred Units and therefore has been incorporated into the Series B Preferred Units liquidation preference amount presented on the balance sheet. The cumulative preferred return on the remaining units is subject to discretion of the Board of Directors.
Liquidation Preference
In the event of any liquidation, dissolution, or winding up of the Company, or a deemed liquidation event, including a merger or consolidation, or a sale or other disposition of all or substantially all of the Company’s assets, the holders shall receive distributions in an amount up to their liquidation preference. See the consolidated balance sheet for the liquidation preference amounts. The preference of distributions is first to Series C-1 Preferred Unit holders, second to Series C Preferred Unit holders, third to Series B Preferred Units holders, fourth to Series A and Series A-1 Preferred Units holders, fifth to Class B-1 Profits Interest Units, until members have received cumulative distributions equal to approximately $9.5 million. After the payment of the full liquidation preference of the redeemable convertible preferred stock and profits interests, the Company’s remaining assets legally available for distribution, if any, would be distributed ratably to the holders of Class A and Class B Common Units.
Classification
A redeemable equity security is to be classified as temporary or mezzanine equity if it is conditionally redeemable upon the occurrence of an event that is not solely within the control of the issuer.
The Preferred Units and Common Units are redeemable for cash upon the occurrence of a deemed liquidation event. As of December 31, 2024 and 2023, a deemed liquidation event is not considered probable, and the occurrence of such an event is considered to be outside of the Company’s control. Accordingly, the Preferred Units and Common Units are considered conditionally redeemable upon the occurrence of an event that is not solely within the control of the issuer and, therefore, the Company has classified the Preferred Units and Common Units as mezzanine equity in the consolidated balance sheets as of December 31, 2024 and 2023. The mezzanine equity amount related to Common Units issued as unit-based compensation is the grant date redemption value, or the modification date redemption value, as applicable. The difference between the grant date fair value and the redemption value for vested awards is presented in additional paid-in capital if the grant date fair value exceeds the redemption value, or accumulated deficit if the grant date fair value is less than the redemption value on the consolidated balance sheets. During the year ended December 31, 2023, the Company recorded an immaterial correction within the period to reflect the grant date redemption value associated with the vested portion of Common Units issued as unit-based compensation in temporary equity and the excess of the grant date fair value over the redemption value for vested awards in accumulated deficit.
NOTE 12 — UNIT-BASED COMPENSATION EXPENSE
Class B-1 Profits Interest Units
On September 12, 2022, the Company issued service-vesting Class B-1 Profits Interest Units in exchange for options previously granted as unit-based compensation. The Class B-1 Profits Interest Units contain a
F-30
catch-up distribution provision payable upon a deemed liquidation event to compensate holders for the loss in appreciated value from the strike price of the options to the profits interest participation threshold. Generally, Class B-1 Profits Interest Units vest 25% on the first vesting date, and an additional 25% on each anniversary of the vesting date until the units are fully vested. The Company has the right to repurchase vested units at fair value upon termination, however the Company does not have plans to exercise this right.
The following table summarizes the activity related to the Company’s Class B-1 Profits Interest awards for the years ended December 31, 2023 and 2024:
| | | |
Number of
Units |
| |
Weighted
Average Grant Date Fair Value |
| ||||||
|
Unvested Class B-1 Units at January 1, 2023
|
| | | | 987,500 | | | | | $ | 3.19 | | |
|
Vested
|
| | | | (593,750) | | | | | | 3.19 | | |
|
Forfeited
|
| | | | (162,500) | | | | | | 3.19 | | |
|
Unvested Class B-1 Units at December 31, 2023
|
| | | | 231,250 | | | | | $ | 3.19 | | |
|
Vested
|
| | | | (231,250) | | | | | | 3.19 | | |
|
Forfeited
|
| | | | — | | | | | | — | | |
|
Unvested Class B-1 Units at December 31, 2024
|
| | | | — | | | | | | — | | |
Issuance of Class B-2 Profits Interest Units
Also on September 12, 2022, the Company issued service-vesting Class B-2 Profits Interest Units to certain employees. The Class B-2 Profits Interest Units have identical rights and participations as the Class B-1 Profits Interests Units with the exception of the catch-up distribution. Class B-2 Profits Interest Units vest 25% on the first vesting date, and an additional 25% on each anniversary of the vesting date until the units are fully vested. The Company has the right to repurchase vested units at fair value upon termination, however the Company does not have plans to exercise this right.
On June 11, 2023, the Company amended its profit interest units which increased the participation threshold and added a SPAC merger transaction as a triggering event for the catch-up distribution discussed above. The post-modification fair value of the profit interest units decreased when compared to the fair value of the profit interest units immediately preceding the modification. Thus, no incremental unit-based compensation expense was recorded related to this modification. As a result of the modification, redemption value for vested awards was remeasured at the modification date, resulting in incremental temporary equity over the life of the awards of $8.76 per unit for the Class B-1 Profits Interest Units and $9.50 per unit for the Class B-2 Profits Interest Units.
The following table summarizes the activity related to the Company’s Class B-2 Profits Interest awards for the years ended December 31, 2023 and 2024:
| | | |
Number of
Units |
| |
Weighted
Average Grant Date Fair Value |
| ||||||
|
Unvested Class B-2 Units at January 1, 2023
|
| | | | 2,465,250 | | | | | $ | 2.34 | | |
|
Vested
|
| | | | (718,500) | | | | | | 2.34 | | |
|
Forfeited
|
| | | | (565,250) | | | | | | 2.34 | | |
|
Unvested Class B-2 Units at December 31, 2023
|
| | | | 1,181,500 | | | | | $ | 2.34 | | |
|
Vested
|
| | | | (464,000) | | | | | | 2.34 | | |
|
Forfeited
|
| | | | (34,500) | | | | | | 2.34 | | |
|
Unvested Class B-2 Units at December 31, 2024
|
| | | | 683,000 | | | | | | 2.34 | | |
Unit-Based Compensation
Unit-based compensation expense of $1.0 million was classified as selling, general, and administrative expense and $0.1 million was classified as a direct expense for the year ended December 31, 2024. Unit- based
F-31
compensation expense of $5.8 million was classified as selling, general, and administrative expense for the year ended December 31 2023. The total fair value of units that vested during the years ended December 31 2024, and 2023 was $1.8 million and $1.7 million, respectively. As of December 31, 2024, the Company had $0.5 million of unrecognized unit-based compensation that is expected to be recognized over a weighted average period of 1.3 years.
NOTE 13 — FAIR VALUE MEASUREMENTS
The liabilities recorded at fair value and measured on a recurring basis are all Level 3 measurements as of December 31, 2024 and 2023.
Rollforward of Level 3 Measurements
A roll forward of the Level 3 measurements as of December 31, 2024 and 2023 is as follows:
| | | |
June 2022
Warrants |
| |
October
2022 Warrants |
| |
December
2022 Warrants |
| |
C-1 Notes
|
| |
C-2 Notes
|
| |
2024
Warrants |
| |
2024
Financial Instrument |
| |
Embedded
Derivatives |
| ||||||||||||||||||||||||
|
Beginning balance as of January 1, 2023
|
| | | $ | 8,311 | | | | | $ | — | | | | | $ | 2,664 | | | | | $ | 48,786 | | | | | $ | 85,490 | | | | | $ | — | | | | | $ | — | | | | | $ | — | | |
|
Conversions
|
| | | | — | | | | | | — | | | | | | — | | | | | | (47,302) | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | |
|
Issuances
|
| | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | 28,000 | | | | | | — | | | | | | — | | | | | | 3,611 | | |
|
Change in Fair Value recognized in other income (expense), net
|
| | | | (5,229) | | | | | | 4,450 | | | | | | (1,752) | | | | | | 21,034 | | | | | | 6,659 | | | | | | — | | | | | | — | | | | | | 2,542 | | |
|
Change in Fair Value
attributable to instrument- specific credit risk recognized in other comprehensive income(1) |
| | | | — | | | | | | — | | | | | | — | | | | | | 3,383 | | | | | | 1,091 | | | | | | — | | | | | | — | | | | | | — | | |
|
Ending balance as of December 31, 2023
|
| | |
$
|
3,082
|
| | | |
$
|
4,450
|
| | | |
$
|
912
|
| | | |
$
|
25,901
|
| | | |
$
|
121,240
|
| | | |
$
|
—
|
| | | |
$
|
—
|
| | | |
$
|
6,153
|
| |
|
Exercises/Settlements
|
| | | | — | | | | | | (5,175) | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | |
|
Conversions
|
| | | | — | | | | | | — | | | | | | — | | | | | | (27,138) | | | | | | (116,800) | | | | | | — | | | | | | — | | | | | | — | | |
|
Issuances
|
| | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | 55,252 | | | | | | 12,266 | | | | | | 3,912 | | |
|
Change in Fair Value recognized in other income (expense), net
|
| | | | 554 | | | | | | 725 | | | | | | 482 | | | | | | 1,237 | | | | | | 7,877 | | | | | | (9,648) | | | | | | (12,266) | | | | | | (10,065) | | |
|
Change in Fair Value
attributable to instrument- specific credit risk recognized in other comprehensive income(1) |
| | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | 6,220 | | | | | | — | | | | | | — | | | | | | — | | |
|
Ending balance as of December 31, 2024
|
| | | $ | 3,636 | | | | | $ | — | | | | | $ | 1,394 | | | | | $ | — | | | | | $ | 18,537 | | | | | $ | 45,604 | | | | | $ | — | | | | | $ | — | | |
(1)
As the fair value option is elected for the C-1 Notes and C-2 Notes, the change in fair value attributable to instrument- specific credit risk associated with each instrument is recorded within other comprehensive income or loss. The remaining change in fair value is recorded within other income (expense), net on the consolidated statements of operations and comprehensive loss. The change in instrument specific credit risk is estimated based on the option adjusted spread of comparable companies and the option adjusted spread of the US high yield index for companies with similar credit ratings.
F-32
Valuation Techniques and Significant Unobservable Inputs
A significant increase or decrease in any of the significant unobservable inputs used in the fair value measurement of the warrant liabilities, derivative liability, C-1 Notes, or C-2 Notes could result in a significantly higher or lower fair value measurement. The quantitative inputs and assumptions used for items categorized in Level III of the fair value hierarchy as of December 31, 2024 and December 31, 2023 are summarized below:
2024 Warrants
The fair value of the 2024 Warrants is based on an option pricing method of allocation. The significant inputs, including significant unobservable inputs, used in the recurring Level 3 fair value measurements of the 2024 Warrants as of December 31, 2024 are as follows:
|
Significant Inputs
|
| |
December 31,
2024 |
| |||
|
Expected term (years)
|
| | | | 1.3 | | |
|
Equity volatility
|
| | | | 58.0% | | |
|
Risk-free rate
|
| | | | 4.1% | | |
June 2022 Warrants
In conjunction with a guarantee to the Bank of New York Credit Facility, the Company issued $10.0 million of warrants (the “June 2022 Warrants”) to Ghaffarian Enterprises on June 30, 2022. The fair value of the June 2022 Warrants is based on an option pricing method of allocation. The significant inputs, including significant unobservable inputs, used in the recurring Level 3 fair value measurements of the June 2022 Warrants as of December 31, 2024 and 2023, are as follows:
| | | |
December 31,
|
| |||||||||
|
Significant Inputs
|
| |
2024
|
| |
2023
|
| ||||||
|
Expected term (years)
|
| | | | 3.2 | | | | | | 4.2 | | |
|
Equity volatility
|
| | | | 63.0% | | | | | | 74.0% | | |
|
Risk-free rate
|
| | | | 4.2% | | | | | | 3.8% | | |
December 2022 Warrants
On December 5, 2022, the Company issued 444,444 warrants (the “December 2022 Warrants”) to purchase common units of the Company. The December 2022 Warrants have an exercise price of $0.01 per unit and are not exercisable until 36 months following the issuance of the C-2 Notes, subject to the achievement of certain business requirements. The December 2022 Warrants are freestanding financial instruments and are liability classified as of December 31, 2024 and 2023. The fair value is determined based on an option pricing method of allocation using the contractual strike price per the warrant agreement, and an estimate of the per unit value of the warrants. The significant inputs, including significant unobservable inputs, used in the recurring Level 3 fair value measurements of the December 2022 Warrants as of December 31, 2024 and 2023 are as follows:
| | | |
December 31,
|
| |||||||||
|
Significant Inputs
|
| |
2024
|
| |
2023
|
| ||||||
|
Expected term (years)
|
| | | | 3.2 | | | | | | 4.2 | | |
|
Equity volatility
|
| | | | 63.0% | | | | | | 74.0% | | |
|
Discount for lack of marketability
|
| | | | 28.0% | | | | | | 30.0% | | |
|
Risk-free rate
|
| | | | 4.2% | | | | | | 3.8% | | |
F-33
C-2 Notes
The fair value of the C-2 Notes is based on the binomial lattice model, which is considered to be a Level 3 fair value measurement. The significant inputs, including significant unobservable inputs, used in the recurring Level 3 fair value measurements of the C-2 Notes as of December 31, 2024 and 2023 are as follows:
| | | |
December 31,
|
| |||||||||
|
Significant Inputs
|
| |
2024
|
| |
2023
|
| ||||||
|
Discount rate
|
| | | | 14.2% | | | | | | 19.8% | | |
|
Credit Spread
|
| | | | 10.0% | | | | | | 14.4% | | |
|
Equity volatility
|
| | | | 56.0% | | | | | | 65.0% | | |
|
Risk-free rate
|
| | | | 4.2% | | | | | | 5.4% | | |
C-1 Notes
The fair value of the C-1 Notes is determined by the discounted cash flow method of the income approach. The significant inputs, including significant unobservable inputs, used in the recurring Level 3 fair value measurements of the C-1 Notes as of December 31, 2024 and 2023 are as follows:
| | | |
December 31,
|
| |||||||||
|
Significant Inputs
|
| |
2024
|
| |
2023
|
| ||||||
|
Discount rate
|
| | | | — | | | | | | 19.4% | | |
October 2022 Warrants
The fair value of the October 2022 Warrants is based on an option pricing method of allocation. During the year ended December 31, 2024, in conjunction with the C-1 Conversion, the October 2022 Warrants were exercised in exchange for 582,094 Series C Preferred Units. The significant inputs, including significant unobservable inputs, used in the recurring Level 3 fair value measurements of the June 2022 Warrants as of December 31, 2023 are as follows:
|
Significant Inputs
|
| |
December 31,
2023 |
| |||
|
Expected term (years)
|
| | | | 4.2 | | |
|
Equity volatility
|
| | | | 74.0% | | |
|
Risk-free rate
|
| | | | 3.8% | | |
Bifurcated Embedded Derivatives
The bifurcated embedded derivatives are comprised of various features associated with the 2023 Bridge Loan, such as the default interest rate feature, event of default redemption feature, and contingent additional interest feature. The bifurcated embedded derivatives were initially recorded at fair value and were revalued at the end of each reporting period. Changes in the fair value of the bifurcated embedded derivatives were recognized in earnings in the period in which the change occurred. The Company determined the fair value of the bifurcated embedded derivatives outstanding at December 31, 2023 by considering the probability that these features would be triggered and their associated cash outflows, which were 50% and $12.3 million, respectively. Due to the Company’s repayment of the 2023 Bridge Loan and its resulting accounting extinguishment during the year ended December 31, 2024, there is no bifurcated embedded derivative liability recorded as of December 31, 2024. See Note 7 — Debt for further information.
NOTE 14 — RELATED PARTY TRANSACTIONS
In the ordinary course of business, the Company enters into transactions with various related parties.
Related Party Revenue
During the year ended December 31, 2023, the Company entered into a joint development agreement (“JDA”) with the Dow Chemical Company (“Dow”). During the years ended December 31, 2024 and 2023,
F-34
the Company entered into projects with two different related parties to provide design and engineering services. The table below summarizes related party revenues that are reflected within revenue in the consolidated statement of operations and comprehensive loss for the years ended December 31, 2024 and 2023 (in thousands):
| | | |
December 31,
2024 |
| |
December 31,
2023 |
| ||||||
|
Revenue associated with Dow
|
| | | $ | 26,848 | | | | | | 5,104 | | |
|
Revenue associated with design and engineering services
|
| | | | 707 | | | | | | 833 | | |
| Total | | | | $ | 27,555 | | | | | $ | 5,937 | | |
Related Party Expenses
The Company enters into various arrangements with related party vendors. These arrangements primarily include subcontracting services and general and administrative services, as well as a credit support fee. For subcontracting services, the Company engages with Hatch Associate Consultants, Inc (“Hatch”), Aerotherm, Inc. (“Aerotherm”), Zachry Nuclear Engineering, Inc. (“Zachry”), Burns & McDonnell Engineering Company, Inc. (“Burns & McDonnell”), Dow Chemical Company (“Dow”), and Curtiss- Wright Corporation (“Curtiss-Wright”). For general and administrative services, the Company engages with IBX, LLC (“IBX”) and IBX 801 Thompson Realty, LLC (“IBX Thompson”). Credit support fees are incurred to Ghaffarian Enterprises, LLC (“Ghaffarian”). Hatch, Zachry, Burns & McDonnell, Dow, and Curtiss-Wright are investors of the Company, and Aerotherm, IBX, IBX Thompson, and Ghaffarian share a common member of management with the Company.
The subcontracting services primarily pertain to support services related to ARDP, and the general and administrative services include rent for office space, consulting services, and other general and administrative services. The credit support fee relates to the Bank of New York Credit Facility described above in Note 7 — Debt. The table below summarizes the expenses with related parties that are reflected in the consolidated statement of operations and comprehensive loss for these categories for the years ended December 31, 2024 and 2023 (in thousands):
| | | |
December 31,
2024 |
| |
December 31,
2023 |
| ||||||
|
Subcontracting services(1)
|
| | | $ | 21,813 | | | | | | 69,803 | | |
|
General and administrative services(2)
|
| | | | 2,515 | | | | | | 3,632 | | |
|
Credit support fee(3)
|
| | | | 903 | | | | | | 2,728 | | |
| Total | | | | $ | 25,231 | | | | | $ | 76,163 | | |
(1)
Expenses relating to subcontracting services are reflected within direct costs in the consolidated statement of operations and comprehensive loss.
(2)
Expenses related to general and administrative services are reflected within selling, general, and administrative expenses in the consolidated statement of operations and comprehensive loss.
(3)
Expenses related to credit support fee are reflected within interest expense in the consolidated statement of operations and comprehensive loss.
Due to/from Related Parties
As of December 31, 2024 and 2023, the following balances were recorded within due from related parties for the above projects (in thousands):
| | | |
December 31,
2024 |
| |
December 31,
2023 |
| ||||||
|
Due from related party related to Dow(1)
|
| | | | 15,774 | | | | | | 3,507 | | |
|
Other
|
| | | | 199 | | | | | | — | | |
| Total | | | | $ | 15,973 | | | | | $ | 3,507 | | |
F-35
(1)
Of the total balance due from related party related to Dow, $7.7 million and $3.3 million is unbilled as of December 31, 2024 and 2023, respectively.
As of December 31, 2024 and 2023, the following balances were recorded within due to related parties for the above services (in thousands):
| | | |
December 31,
2024 |
| |
December 31,
2023 |
| ||||||
|
Due to related parties for subcontracting services
|
| | | | 7,464 | | | | | | 14,267 | | |
|
Due to related parties for general and administrative services
|
| | | | 186 | | | | | | 1,828 | | |
|
Due to related parties for credit support fee
|
| | | | — | | | | | | 1,989 | | |
|
Deferred revenue with related parties
|
| | | | 569 | | | | | | — | | |
|
Other
|
| | | | 261 | | | | | | 64 | | |
| Total | | | | $ | 8,480 | | | | | $ | 18,148 | | |
See Note 7 — Debt for disclosure related to debt from related parties.
NOTE 15 — COMMITMENTS AND CONTINGENCIES
Incurred Cost Audits
The Company predominantly performs contract services for the DoE. The Company’s costs incurred on such contracts with the DoE are subject to final incurred cost audits prior to the close out of the award as specified in such contracts. Billings under this contract are based on provisional rates that permit recovery of allowable overhead, and general and administrative expenses not exceeding certain limits. These rates are subject to review by the government on an annual basis. When final determination and approval of the allowable rates have been made, billings may be adjusted.
The Company is currently undergoing audits of the costs incurred through December 31, 2023. As of December 31, 2024 and 2023, the Company expects the impact of any cost audit findings to be immaterial.
Investigations and Litigation
From time to time the Company may become involved in legal proceedings or be subject to claims arising in the ordinary course of its business. The Company is not, to the best of its knowledge, presently a party to any legal proceedings that, if determined adverse to the Company, would individually or taken together have a material adverse effect on its business, operating results, financial condition, or cash flows.
NOTE 16 — SUPPLEMENTAL CASH FLOW INFORMATION
Supplemental cash flow disclosures are as follows (in thousands):
| | | |
December 31,
2024 |
| |
December 31,
2023 |
| ||||||
|
Cash Paid for Interest
|
| | | $ | 4,621 | | | | | $ | 756 | | |
| Non-Cash Investing and Financing Activities: | | | | | | | | | | | | | |
|
Conversion of C-1 & C-2 Notes to Series C Preferred Units
|
| | | | 126,354 | | | | | | 47,302 | | |
|
Conversion of 2024 Convertible Note to Series C-1 Preferred Units
|
| | | | 20,093 | | | | | | — | | |
|
Valuation of Derivative Liability
|
| | | | 3,912 | | | | | | 6,153 | | |
|
Class B Common Units related to the issuance and exchange of debt
|
| | | | 9,061 | | | | | | — | | |
|
Accrued debt issuance costs
|
| | | | 369 | | | | | | 1,125 | | |
|
Government grant reimbursement receivable for purchase of property and equipment
|
| | | | 5,359 | | | | | | — | | |
|
Property and equipment included in accounts payable and accrued expenses
|
| | | | 6,527 | | | | | | — | | |
F-36
NOTE 17 — SEGMENTS
Under the guidelines of ASC 280, which require companies to present financial information about their operating segments, products and services, geographic regions, and significant customers, the Company’s Chief Executive Officer serves as the chief operating decision maker (“CODM”). The CODM evaluates financial performance, allocates resources, and makes strategic decisions based on the consolidated results of the Company, rather than evaluating discrete lines of business. Accordingly, management has determined that the Company comprises a single reportable segment.
In making resource allocation and assessing operational outcomes, the CODM relies on overall net income (loss) as the primary metric both during the annual planning process and for evaluating results on a quarterly basis. The primary expenses presented to the CODM and incorporated in segment performance are related to the operating expenses; direct costs, selling, general and administrative costs, and research and development costs — as well as the non-operating expenses; interest expense, interest income, and other income (expense). The consolidated statements of operations for the years ended December 31, 2024 and 2023 present these significant segment expenses for the Company’s single operating segment. The consolidated balance sheets as of December 31, 2024 and 2023 likewise display the assets and liabilities attributable to this single segment.
NOTE 18 — SUBSEQUENT EVENTS
In preparing these financial statements, the Company has evaluated subsequent events to determine if any require recognition or disclosure. Subsequent events have been evaluated through November 11, 2025, the date the financial statements were available to be issued.
Additional Issuance of Series C-1 Preferred Units
On January 24, 2025, the Company completed additional financing rounds of Series C-1 Preferred Units, receiving gross cash proceeds of approximately $53.4 million from various investors. As a result of this financing round, the Company issued 8,235,521 Series C-1 Preferred Units.
Issuance of Additional Class B-2 Profits Interest Units
On May 7, 2025, the Company issued an aggregate of 9,795,000 additional Class B-2 Profits Interest Units to certain employees.
C-2 Note Conversion
On September 30, 2025, the outstanding principal and unpaid accrued interest on the C-2 Note were converted into 2,870,172 Series C Preferred Units, resulting in the extinguishment of the C-2 Note.
2025 Warrant Issuance
On October 3, 2025, the Company issued the 2025 Warrant to a related party to purchase up to 14,123,859 Series C-1 Preferred Units at an exercise price of $6.4870 per unit.
F-37
X-ENERGY REACTOR COMPANY, LLC
CONDENSED CONSOLIDATED BALANCE SHEETS
(In thousands, except units)
(Unaudited)
(In thousands, except units)
(Unaudited)
| | | |
September 30,
2025 |
| |
December 31,
2024 |
| ||||||
| ASSETS | | | | | | | | | | | | | |
| Current assets | | | | | | | | | | | | | |
|
Cash and cash equivalents
|
| | | $ | 426,815 | | | | | $ | 514,600 | | |
|
Accounts receivable
|
| | | | 29,410 | | | | | | 1,212 | | |
|
Unbilled receivables and contract assets
|
| | | | 26,697 | | | | | | 27,211 | | |
|
Prepaid and other current assets
|
| | | | 9,010 | | | | | | 2,894 | | |
|
Due from related parties
|
| | | | 4,818 | | | | | | 15,973 | | |
|
Total current assets
|
| | | | 496,750 | | | | | | 561,890 | | |
|
Restricted cash
|
| | | | 3,687 | | | | | | — | | |
|
Property and equipment, net
|
| | | | 37,232 | | | | | | 5,828 | | |
|
Operating lease right-of-use assets
|
| | | | 22,756 | | | | | | 11,003 | | |
|
Other long-term assets
|
| | | | 1,274 | | | | | | 789 | | |
|
Total assets
|
| | | $ | 561,699 | | | | | $ | 579,510 | | |
| LIABILITIES, MEZZANINE EQUITY, AND MEMBERS’ DEFICIT | | | | | | | | | | | | | |
| Current liabilities | | | | | | | | | | | | | |
|
Short-term borrowings
|
| | | | — | | | | | $ | 18,537 | | |
|
Accounts payable
|
| | | | 7,875 | | | | | | 2,327 | | |
|
Accrued liabilities
|
| | | | 40,356 | | | | | | 35,379 | | |
|
Due to related parties
|
| | | | 4,925 | | | | | | 8,480 | | |
|
Total current liabilities
|
| | | | 53,156 | | | | | | 64,723 | | |
|
Long-term operating lease liabilities
|
| | | | 19,012 | | | | | | 10,338 | | |
|
Warrant liabilities
|
| | | | 256,620 | | | | | | 50,634 | | |
|
Total liabilities
|
| | | | 328,788 | | | | | | 125,695 | | |
| Mezzanine equity | | | | | | | | | | | | | |
|
Class A Common Units: 345,682,855 units authorized, 3,128,026 units issued and outstanding as of September 30, 2025, and 328,688,824 units authorized, 3,128,026 units issued and outstanding as of and December 31, 2024
|
| | | | 1,800 | | | | | | 1,800 | | |
|
Class B Common Units: 34,043,242 units authorized, 16,800,955 units issued and outstanding as of September 30, 2025, and 34,043,242 units authorized, 13,960,705 units issued and outstanding as of December 31, 2024
|
| | | | 92,913 | | | | | | 90,859 | | |
|
Series A redeemable convertible preferred units: 90,625,588 units authorized, issued and outstanding as of
September 30, 2025 and December 31, 2024; liquidation preference of $52,146 as of September 30, 2025 and December 31, 2024 |
| | | | 218,408 | | | | | | 218,408 | | |
|
Series A-1 redeemable convertible preferred units: 8,808,351 units authorized, issued and outstanding as of
September 30, 2025 and December 31, 2024; liquidation preference of $67,250 as of September 30, 2025 and December 31, 2024 |
| | | | 21,477 | | | | | | 21,477 | | |
|
Series B redeemable convertible preferred units: 11,643,171 units authorized, issued and outstanding as of September 30, 2025 and December 31, 2024; liquidation preference of $119,412 as of September 30, 2025 and $117,030 as of December 31, 2024
|
| | | | 101,382 | | | | | | 101,382 | | |
|
Series C redeemable convertible preferred units: 68,055,415 units authorized; 39,963,592 units issued and outstanding as of September 30, 2025, and 65,185,243 units authorized; 37,093,420 units issued and outstanding as of December 31, 2024; liquidation preference of $305,114 as of September 30, 2025 and $283,201 as of December 31, 2024
|
| | | | 265,797 | | | | | | 230,987 | | |
|
Series C-1 redeemable convertible preferred units: 162,246,180 units authorized; 107,908,114 units issued and
outstanding as of September 30, 2025, and 148,122,321 units authorized, 99,672,593 units outstanding as of December 31, 2024; liquidation preference of $875,000 as of September 30, 2025 and $808,220 as of December 31, 2024 |
| | | | 686,715 | | | | | | 635,463 | | |
|
Total mezzanine equity
|
| | | | 1,388,492 | | | | | | 1,300,376 | | |
|
Accumulated deficit
|
| | | | (1,164,645) | | | | | | (846,567) | | |
|
Accumulated other comprehensive income
|
| | | | 176 | | | | | | 6 | | |
|
Additional paid-in capital
|
| | | | 8,888 | | | | | | — | | |
|
Total members’ deficit
|
| | | | (1,155,581) | | | | | | (846,561) | | |
|
Total liabilities, mezzanine equity, and members’ deficit
|
| | | $ | 561,699 | | | | | $ | 579,510 | | |
F-38
X-ENERGY REACTOR COMPANY, LLC
CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS AND COMPREHENSIVE LOSS
(In thousands)
(Unaudited)
(In thousands)
(Unaudited)
| | | |
Nine Months Ended
September 30, |
| |||||||||
| | | |
2025
|
| |
2024
|
| ||||||
|
Services revenue(1)
|
| | | $ | 60,411 | | | | | $ | 60,314 | | |
|
Grant income
|
| | | | 12,324 | | | | | | 25,674 | | |
|
Total revenues and grant income
|
| | | | 72,735 | | | | | | 85,988 | | |
| Operating expenses | | | | | | | | | | | | | |
|
Direct costs
|
| | | | 103,679 | | | | | | 98,926 | | |
|
Selling, general and administrative
|
| | | | 77,451 | | | | | | 40,523 | | |
|
Research and development
|
| | | | 1,376 | | | | | | 964 | | |
|
Total operating expenses
|
| | | | 182,506 | | | | | | 140,413 | | |
|
Operating loss
|
| | | | (109,771) | | | | | | (54,425) | | |
| Other income (expense) | | | | | | | | | | | | | |
|
Interest expense
|
| | | | (476) | | | | | | (15,917) | | |
|
Interest income
|
| | | | 14,824 | | | | | | — | | |
|
Other expense, net
|
| | | | (222,655) | | | | | | (8,377) | | |
|
Total other income (expense), net
|
| | | | (208,307) | | | | | | (24,294) | | |
|
Net loss
|
| | | | (318,078) | | | | | | (78,719) | | |
| Other comprehensive income (loss) | | | | | | | | | | | | | |
|
Foreign currency translation adjustment
|
| | | | (595) | | | | | | (158) | | |
|
Reclassification of OCI for conversion of C-1 and C-2 Notes
|
| | | | 321 | | | | | | (1,272) | | |
|
Changes in fair value of liabilities under fair value option attributable to changes in
instrument-specific credit risk |
| | | | 444 | | | | | | (6,396) | | |
|
Other comprehensive income (loss)
|
| | | | 170 | | | | | | (7,826) | | |
|
Comprehensive loss
|
| | | $ | (317,908) | | | | | $ | (86,545) | | |
(1)
Includes related party revenue of $6,320 and $19,257 for the nine months ended September 30, 2025 and 2024, respectively.
F-39
X-ENERGY REACTOR COMPANY, LLC
CONDENSED CONSOLIDATED STATEMENTS OF CHANGES IN MEMBERS’ DEFICIT AND MEZZANINE EQUITY
(In thousands, except units)
(Unaudited)
(In thousands, except units)
(Unaudited)
| | | |
Accumulated
Deficit |
| |
Accumulated
Other Comprehensive Income (Loss) |
| |
Additional
Paid-In Capital |
| |
Total
Members’ Deficit |
| | |
Class A
Common Units |
| |
Class B
Common Units |
| |
Series A
Preferred Units |
| |
Series A-1
Preferred Units |
| |
Series B
Preferred Units |
| |
Series C
Preferred Units |
| |
Series C-1
Preferred Units |
| |
Total
Mezzanine Equity |
| ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| |
Units
|
| |
Amount
|
| |
Units
|
| |
Amount
|
| |
Units
|
| |
Amount
|
| |
Unit
|
| |
Amount
|
| |
Units
|
| |
Amount
|
| |
Unit
|
| |
Amount
|
| |
Unit
|
| |
Amount
|
| |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
|
Balance, January 1, 2024
|
| | | $ | (716,769) | | | | | $ | 879 | | | | |
|
—
|
| | | | $ | (715,890) | | | | | | | 3,128,026 | | | | | $ | 1,800 | | | | | | 10,139,818 | | | | | $ | 74,250 | | | | | | 90,625,588 | | | | | $ | 218,408 | | | | | | 8,808,351 | | | | | $ | 21,477 | | | | | | 11,643,171 | | | | | $ | 101,382 | | | | | | 16,340,900 | | | | | $ | 99,458 | | | | |
|
—
|
| | | |
|
—
|
| | | | $ | 516,775 | | |
|
Unit-based compensation
|
| | | | (3,116) | | | | | | — | | | | | | — | | | | | | (3,116) | | | | | | | — | | | | | | — | | | | | | 694,000 | | | | | | 4,067 | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | 4,067 | | |
|
Issuance of Class B Units in conjunction with the issuance and modification of debt
|
| | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | | — | | | | | | — | | | | | | 2,369,752 | | | | | | 9,061 | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | 9,061 | | |
|
Issuance of Class B Units in
conjunction with the conversion of C-1 Notes to Series C Preferred Units |
| | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | | — | | | | | | — | | | | | | 757,135 | | | | | | 2,560 | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | 2,560 | | |
|
Conversion of Series C-1 Notes into Series C Preferred Units
|
| | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | 3,210,405 | | | | | | 27,138 | | | | | | — | | | | | | — | | | | | | 27,138 | | |
|
Exercise of the October 2022
Warrants |
| | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | 582,094 | | | | | | 5,175 | | | | | | — | | | | | | — | | | | | | 5,175 | | |
|
Net loss
|
| | | | (78,719) | | | | | | — | | | | | | — | | | | | | (78,719) | | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | |
|
Foreign currency translation adjustment
|
| | | | — | | | | | | (158) | | | | | | — | | | | | | (158) | | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | |
|
Changes in fair value of liabilities
under fair value option attributable to changes in instrument specific credit risk |
| | | | — | | | | | | (6,396) | | | | | | — | | | | | | (6,396) | | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | |
|
Reclassification of OCI for conversion of C-1 and
C-2 Notes |
| | | | — | | | | | | (1,272) | | | | | | — | | | | | | (1,272) | | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | |
|
Balance, September 30, 2024
|
| | | $ | (798,604) | | | | | $ | (6,947) | | | | | | — | | | | | $ | (805,551) | | | | | | | 3,128,026 | | | | | $ | 1,800 | | | | | | 13,960,705 | | | | | $ | 89,938 | | | | | | 90,625,588 | | | | | $ | 218,408 | | | | | | 8,808,351 | | | | | $ | 21,477 | | | | | | 11,643,171 | | | | | $ | 101,382 | | | | | | 20,133,399 | | | | | $ | 131,771 | | | | | | — | | | | | | — | | | | | $ | 564,776 | | |
|
Balance, January 1, 2025
|
| | | $ | (846,567) | | | | | $ | 6 | | | | | | — | | | | | $ | (846,561) | | | | | | | 3,128,026 | | | | | $ | 1,800 | | | | | | 13,960,705 | | | | | $ | 90,859 | | | | | | 90,625,588 | | | | | $ | 218,408 | | | | | | 8,808,351 | | | | | $ | 21,477 | | | | | | 11,643,171 | | | | | $ | 101,382 | | | | | | 37,093,420 | | | | | $ | 230,987 | | | | | | 99,672,593 | | | | | $ | 635,463 | | | | | $ | 1,300,376 | | |
|
Unit-based compensation
|
| | | | — | | | | | | — | | | | | | 8,888 | | | | | | 8,888 | | | | | | | — | | | | | | — | | | | | | 2,840,250 | | | | | | 2,054 | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | 2,054 | | |
|
Issuance of Series C-1 Preferred Units, net of issuance costs
|
| | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | 8,235,521 | | | | | $ | 51,252 | | | | | | 51,252 | | |
|
Conversion of C-2 Notes
|
| | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | 2,870,172 | | | | | | 34,810 | | | | | | — | | | | | | — | | | | | | 34,810 | | |
|
Net loss
|
| | | | (318,078) | | | | | | — | | | | | | — | | | | | | (318,078) | | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | |
|
Foreign currency translation adjustment
|
| | | | — | | | | | | (595) | | | | | | — | | | | | | (595) | | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | |
|
Changes in fair value of liabilities
under fair value option attributable to changes in instrument specific credit risk |
| | | | — | | | | | | 321 | | | | | | — | | | | | | 321 | | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | |
|
Reclassification of OCI for conversion of C-2 Notes
|
| | | | — | | | | | | 444 | | | | | | — | | | | | | 444 | | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | |
|
Balance, September 30, 2025
|
| | | $ | (1,164,645) | | | | | $ | 176 | | | | | $ | 8,888 | | | | | $ | (1,155,581) | | | | | | | 3,128,026 | | | | | $ | 1,800 | | | | | | 16,800,955 | | | | | $ | 92,913 | | | | | | 90,625,588 | | | | | $ | 218,408 | | | | | | 8,808,351 | | | | | $ | 21,477 | | | | | | 11,643,171 | | | | | $ | 101,382 | | | | | | 39,963,592 | | | | | $ | 265,797 | | | | | | 107,908,114 | | | | | $ | 686,715 | | | | | $ | 1,388,492 | | |
F-40
X-ENERGY REACTOR COMPANY, LLC
CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
(In thousands)
(Unaudited)
(In thousands)
(Unaudited)
| | | |
For the Nine Months Ended
September 30, |
| |||||||||
| | | |
2025
|
| |
2024
|
| ||||||
| Cash flows from operating activities: | | | | | | | | | | | | | |
|
Net loss
|
| | | $ | (318,078) | | | | | $ | (78,719) | | |
| Adjustments to reconcile net loss to net cash used in operating activities: | | | | | | | | | | | | | |
|
Depreciation and amortization
|
| | | | 926 | | | | | | 680 | | |
|
Unit-based compensation
|
| | | | 10,593 | | | | | | 951 | | |
|
Loss on extinguishment of debt
|
| | | | — | | | | | | 6,814 | | |
|
Loss on conversion of C-1 & C-2 Notes
|
| | | | 4,023 | | | | | | 14,826 | | |
|
Payable in-kind interest
|
| | | | — | | | | | | 3,446 | | |
|
Mark-to-market loss on warrant liabilities
|
| | | | 205,986 | | | | | | 2,044 | | |
|
Mark-to-market loss on C-1 & C-2 Notes
|
| | | | 12,694 | | | | | | 8,278 | | |
|
Mark-to-market gain on derivative liabilities
|
| | | | — | | | | | | (10,065) | | |
|
Mark-to-market gain on 2024 Financial Instrument
|
| | | | — | | | | | | (12,266) | | |
|
Reclassification of OCI for conversion of C-1 & C-2 Notes
|
| | | | 321 | | | | | | (1,272) | | |
|
Amortization of deferred transaction costs, debt discount, and other
|
| | | | 489 | | | | | | 11,826 | | |
| Changes in operating assets and liabilities: | | | | | | | | | | | | | |
|
Accounts receivable, unbilled receivables, and contract assets
|
| | | | (12,524) | | | | | | 8,847 | | |
|
Prepaid and other current assets
|
| | | | (4,404) | | | | | | (2,828) | | |
|
Due from related parties
|
| | | | 11,155 | | | | | | (8,592) | | |
|
Operating lease right-of use assets
|
| | | | 382 | | | | | | 2,016 | | |
|
Accounts payable and accrued liabilities
|
| | | | 1,761 | | | | | | 10,986 | | |
|
Other long-term assets
|
| | | | (377) | | | | | | 470 | | |
|
Due to related parties
|
| | | | (3,555) | | | | | | (3,518) | | |
|
Operating lease liabilities
|
| | | | (2,070) | | | | | | (1,885) | | |
|
Net cash used in operating activities
|
| | | $ | (92,678) | | | | |
$
|
(47,961)
|
| |
| Cash flows from investing activities: | | | | | | | | | | | | | |
|
Capital expenditures
|
| | | | (79,319) | | | | | | (299) | | |
|
Reimbursement of capital expenditures under government grant
|
| | | | 37,553 | | | | | | 42 | | |
|
Net cash used in investing activities
|
| | | $ | (41,766) | | | | | $ | (257) | | |
| Cash flows from financing activities: | | | | | | | | | | | | | |
|
Borrowings on bridge loans
|
| | | | — | | | | | | 49,598 | | |
|
Repayments on lines of credit
|
| | | | — | | | | | | (75,066) | | |
|
Borrowings from lines of credit
|
| | | | — | | | | | | 89,455 | | |
|
Payments of mezzanine equity issuance costs
|
| | | | (2,697) | | | | | | — | | |
|
Payment of debt issuance costs
|
| | | | (497) | | | | | | (1,801) | | |
|
Proceeds from Series C-1 Preferred Units
|
| | | | 53,424 | | | | | | — | | |
|
Net cash provided by financing activities
|
| | | $ | 50,230 | | | | | $ | 62,186 | | |
|
Net effect of exchange rate
|
| | | | 116 | | | | | | (31) | | |
|
Net increase (decrease) in cash, cash equivalents, and restricted cash
|
| | | | (84,098) | | | | | | 13,937 | | |
|
Cash, cash equivalents and restricted cash at beginning of period
|
| | | | 514,600 | | | | | | 14,398 | | |
|
Cash, cash equivalents and restricted cash at end of period
|
| | | $ | 430,502 | | | | | $ | 28,335 | | |
F-41
X-ENERGY REACTOR COMPANY, LLC
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
(Unaudited)
(Unaudited)
NOTE 1 — ORGANIZATION AND NATURE OF BUSINESS
Company Overview
X-Energy Reactor Company, LLC (“X-energy” or the “Company” or “its”) is a Delaware limited liability company formed on December 14, 2018, and is the predecessor for financial reporting purposes of X-energy, LLC, a Maryland limited liability company founded in 2009. The Company is headquartered in Rockville, Maryland. The Company is a developer of advanced small modular nuclear reactors and fuel technology for clean energy generation.
NOTE 2 — SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES AND RECENT ACCOUNTING PRONOUNCEMENTS
Basis of Presentation
The accompanying unaudited condensed consolidated financial statements of the Company have been prepared using principles generally accepted in the United States of America (“U.S. GAAP”) and pursuant to the rules and regulations of the Securities and Exchange Commission (“SEC”). Certain information and footnote disclosures normally included in annual consolidated financial statements prepared in accordance with U.S. GAAP have been condensed or omitted pursuant to such rules and regulations. The accompanying unaudited condensed consolidated financial statements should be read in conjunction with the annual consolidated financial statements. In the opinion of management, the condensed consolidated financial statements reflect all normal recurring adjustments the Company considers necessary for the fair presentation of its results of operations and cash flows for the interim periods covered, and of the financial position of the Company at the date of the interim condensed consolidated balance sheet. The interim results reported herein are not necessarily indicative of results for a full year. All intercompany balances and transactions have been eliminated in consolidation.
Certain Significant Risks and Uncertainties
Financial instruments that potentially subject the Company to concentrations of credit risk consist principally of cash, cash equivalents, and restricted cash, accounts receivable, and unbilled receivables and contract assets. By their nature, all such financial instruments involve risks, including the credit risk of nonperformance by counterparties. The Company generally does not require collateral to support the obligations of the counterparties and cash levels held at banks may be in excess of federally insured limits. The Company limits its exposure to credit loss by maintaining its cash, cash equivalents, and restricted cash at highly rated financial institutions. The Company has not experienced material losses on its deposits of cash, cash equivalents, and restricted cash. Further, the Company’s revenue and credit relationships are primarily concentrated within the United States Government which represents a concentration risk but a low credit risk.
For the nine months ended September 30, 2025, two customers, the United States Government and Dow Chemical Company (“Dow”), accounted for 83% and 9%, respectively, of the Company’s total revenue and grant income. For the nine months ended September 30, 2024, two customers, the United States Government and Dow, accounted for 74% and 22%, respectively, of the Company’s total revenue and grant income. Refer to Note 3 — Revenue Recognition for further disaggregation of revenue and grant income by customer for the nine months ended September 30, 2025 and 2024.
As of September 30, 2025 and December 31, 2024, the Company’s receivable balances related to services revenue and government grants with the United States Department of Energy (“DoE”) and United States
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Department of Defense (“DoD”) are as follows (in thousands). Refer to Note 13 — Related Party Transactions for further information on receivable balances with Dow.
| | | |
September 30,
2025 |
| |
December 31,
2024 |
| ||||||
| Accounts Receivable | | | | | | | | | | | | | |
|
DoE
|
| | | $ | 27,491 | | | | | | — | | |
| Unbilled Receivables and Contract Assets | | | | | | | | | | | | | |
|
DoE
|
| | | $ | 23,348 | | | | | $ | 23,794 | | |
|
DoD
|
| | | | 1,201 | | | | | | 2,690 | | |
Other Comprehensive Income (Loss)
Other comprehensive income (loss) refers to revenues, expenses, gains, and losses that under GAAP are included in comprehensive income but excluded from net income. The components of the Company’s other comprehensive income (loss) consist of foreign currency translation adjustments, the reclassification of other comprehensive income for the conversion of C-1 and C-2 Notes, and the change in fair value of financial liabilities accounted for pursuant to the fair value option attributable to changes in instrument-specific credit risk.
The components of accumulated other comprehensive income (loss) for the nine months ended September 30, 2025 and September 30, 2024 are as follows (in thousands):
| | | |
Changes in fair
value of liabilities under fair value option attributable to changes in instrument-specific credit risk |
| |
Reclassification
of OCI for conversion of C-1 and C-2 Notes |
| |
Foreign
currency translation adjustment |
| |
Total
|
| ||||||||||||
|
Accumulated other comprehensive loss, balance at December 31, 2023
|
| | | $ | 2,303 | | | | | $ | (1,721) | | | | | $ | 297 | | | | | $ | 879 | | |
|
Other comprehensive income (loss)
|
| | | | (6,396) | | | | | | (1,272) | | | | | | (158) | | | | | | (7,826) | | |
|
Accumulated other comprehensive income (loss), balance at September 30, 2024
|
| | | $ | (4,093) | | | | | $ | (2,993) | | | | | $ | 139 | | | | | $ | (6,947) | | |
|
Accumulated other comprehensive loss, balance at December 31, 2024
|
| | | $ | (3,917) | | | | | $ | 3,152 | | | | | $ | 771 | | | | | $ | 6 | | |
|
Other comprehensive income (loss)
|
| | | | 444 | | | | | | 321 | | | | | | (595) | | | | | | 170 | | |
|
Accumulated other comprehensive income (loss), balance at September 30, 2025
|
| | | $ | (3,473) | | | | | $ | 3,473 | | | | | $ | 176 | | | | | $ | 176 | | |
Cash
The components of cash, cash equivalents, and restricted cash as of September 30, 2025 and December 31, 2024 are as follows:
| | | |
September 30,
2025 |
| |
December 31,
2024 |
| ||||||
|
Cash and cash equivalents
|
| | | $ | 426,815 | | | | | $ | 514,600 | | |
|
Restricted cash
|
| | | | 3,687 | | | | | | — | | |
|
Cash, cash equivalents, and restricted cash as presented in the Statement
of Cash Flows |
| | | $ | 430,502 | | | | | $ | 514,600 | | |
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Deferred Transaction Costs
The Company has recorded deferred transaction costs incurred in conjunction with its debt obligations that are held at amortized cost. The Company amortizes deferred transaction costs over the remaining life of the related debt and records the amortization within interest expense.
In connection with the issuance and amendments of the non-convertible debt, the Company incurred third-party debt issuance costs in the amount of $0.5 million and $2.9 million during the nine months ended September 30, 2025 and 2024, respectively. The debt issuance costs are treated as a debt discount and are amortized over the term of the related loan. During the nine months ended September 30, 2025 and 2024, $0.5 million and $4.8 million, respectively, of amortization expense related to the discount created from the deferred transaction costs was recorded to interest expense on the condensed consolidated statements of operations.
The Company records deferred transaction costs incurred in conjunction with the issuance of preferred units as a reduction of mezzanine equity on the condensed consolidated balance sheets. For the nine months ended September 30, 2025, the Company incurred $2.2 million in issuance costs associated with the issuance of the Series C-1 Preferred Units. No material issuance costs were incurred associated with the issuance of equity during the nine months ended September 30, 2024.
The Company has capitalized qualified legal, accounting, and other direct and incremental costs related to the potential public offering transaction within prepaid and other current assets. As of September 30, 2025, $1.4 million was recognized in prepaid and other current assets related to deferred transaction costs related to the potential public offering.
Other Expense, Net
Other expense, net for the nine months ended September 30, 2025 and 2024 consists of the following (in thousands):
| | | |
Nine Months Ended
September 30, |
| |||||||||
| | | |
2025
|
| |
2024
|
| ||||||
|
Foreign currency transaction gain
|
| | | $ | 367 | | | | | $ | 351 | | |
|
Mark-to-market loss on C-1 & C-2 Notes(1)
|
| | | | (12,694) | | | | | | (8,278) | | |
|
Loss on conversion of C-1 & C-2 Notes(1)
|
| | | | (4,023) | | | | | | (14,826) | | |
|
Mark-to-market loss on warrant liabilities(2)
|
| | | | (205,986) | | | | | | (2,044) | | |
|
Mark-to-market gain on embedded derivatives(1)
|
| | | | — | | | | | | 10,065 | | |
|
Mark-to-market gain on 2024 Financial Instrument(1)
|
| | | | — | | | | | | 12,266 | | |
|
Reclassification of OCI for conversion of C-1 & C-2 Notes(1)
|
| | | | (321) | | | | | | 1,272 | | |
|
Loss on extinguishment of debt(1)
|
| | | | — | | | | | | (6,814) | | |
|
Other expense
|
| | | | 2 | | | | | | (369) | | |
|
Total other expense, net
|
| | | $ | (222,655) | | | | | $ | (8,377) | | |
(1)
Refer to Note 7 — Debt.
(2)
Refer to Note 12 — Fair Value Measurements.
Unit-Based Compensation
Unit-based compensation represents costs related to unit-based awards granted to employees and members of the Board of Directors. The Company recognizes unit-based compensation, utilizing the accelerated attribution method, based upon the estimated fair value of awards on the grant date for equity classified awards. Forfeitures are accounted for as they occur. The recognition period for these costs begins at either the applicable service inception date or grant date and continues throughout the requisite service period. Due to the contingently redeemable nature of Class B Common Units (inclusive of the Class B-1 Common
F-44
Units and Class B-2 Common Units, as discussed in Note 10 — Member Units and Preferred Units and Note 12 — Unit-Based Compensation Expense), the Company classifies these units as mezzanine equity and records the redemption value as of the grant date for vested awards within mezzanine equity on the condensed consolidated balance sheets.
Income Taxes
The Company is a limited liability company which is classified as a partnership for U.S. federal and state income tax purposes. Accordingly, the Company’s U.S. operations are not subject to income taxes in the U.S. The Company’s owners separately account for their pro rata share of the Company’s income, deductions, losses and credits annually. The Company’s foreign operations are subject to income taxes in the foreign jurisdictions in which they operate. Income tax expense and benefit were immaterial for the nine months ended September 30, 2025 and 2024.
On July 4, 2025, the One Big Beautiful Bill Act (“OBBBA”) was signed into law. The legislation was a sweeping tax and spending law which makes permanent many provisions of the 2017 Tax Cuts and Jobs Act, while introducing new tax policies and restructuring others. OBBBA does not currently have a material impact to the Company.
Recent Accounting Principles Not Yet Adopted
In December 2023, the FASB issued ASU No. 2023-09, Income Taxes (Topic 740): Improvements to Income Tax Disclosures (“ASU 2023-09”), to enhance the transparency and decision usefulness of income tax disclosures. ASU 2023-09 is effective for annual periods beginning after December 15, 2025 on a prospective basis and early adoption is permitted. The Company is currently evaluating the impact of the adoption of this standard on its consolidated financial statements and related disclosures.
In November 2024, the FASB issued ASU No. 2024-03, Income Statement — Reporting Comprehensive Income — Expense Disaggregation Disclosures (Subtopic 220-40): Disaggregation of Income Statement Expenses (“ASU 2024-03”), which requires public business entities to provide enhanced disclosures about certain categories of expenses in the notes to the financial statements. The guidance is intended to improve the transparency and decision usefulness of expense information provided to financial statement users. The ASU is effective for fiscal years beginning after December 15, 2026, and interim periods within fiscal years beginning after December 15, 2027. Early adoption is permitted. The Company is currently evaluating the impact of this standard on its consolidated financial statements and related disclosures.
In November 2024, the FASB issued ASU No. 2024-04, Debt with Conversion and Other Options (Subtopic 470-20): Induced Conversions of Convertible Debt Instruments (“ASU 2024-04”), which clarifies the assessment of whether certain settlements of convertible debt instruments should be accounted for as an inducement conversion or extinguishment of convertible debt. ASU 2024-04 is effective for annual periods beginning after December 15, 2025 on either a prospective or retrospective basis and early adoption is permitted. The Company does not expect the adoption of this standard to have a material impact on its consolidated financial statements and related disclosures.
NOTE 3 — REVENUE AND GRANT INCOME RECOGNITION
The Company recognizes revenue under contracts with customers to provide nuclear reactor and fuel design engineering services in the areas of research and development, systems engineering, and technology development. The Company’s revenues are generally derived from contract services predominantly performed for the U.S. Government and commercial entities. All revenues for the nine months ended September 30, 2025 and 2024 were recognized over time.
There are two main types of contracts: cost-based contracts and cost plus fixed fee contracts. The total consideration in the Company’s contracts is paid in the form of incremental incurred cost reimbursements over time upon the delivery of the Company’s invoices.
The allowability of certain costs under government contracts is subject to audit by the government. Certain indirect costs are charged to contracts using provisional or estimated indirect rates, which are subject to later revision based on actual costs incurred and subject to government audits of those costs. The
F-45
government has performed audits of the Company’s costs. Refer to Note 14 — Commitments and Contingencies, for further discussion of these cost audits.
Advanced Reactor Demonstrator Program
During the year ended December 31, 2021, the Company was named an awardee under the Department of Energy’s Advanced Reactor Demonstrator Program (“ARDP”). The objective of the ARDP is to accelerate the development and demonstration of advanced nuclear reactor technologies, focusing on designs that improve safety, efficiency, and economic viability for commercial deployment. Under the agreement, the Company will develop the Xe-100 demonstrator reactor, the TRISO-X commercial fuel fabrication facility, and the helium test facility through a public-private cost-share partnership. The DoE will obtain rights to the intellectual property (“IP”) developed under ARDP but will not obtain ownership of the demonstrator reactor or fuel facility. The DoE will fund a portion of the direct and indirect costs incurred for the research and development costs to develop the IP and the costs of developing and constructing both the TRISO-X fuel facility and Xe-100 demonstrator reactor. The program provides for a 50% reimbursement of up to $2.4 billion of eligible costs ($1.2 billion reimbursement) through 2027. The funding is subject to future government appropriations which may not occur, and the government is able to cancel the contract at any time without incurring a substantive penalty. Dow has been named a subawardee under the ARDP in connection with their involvement with the development and construction of the demonstrator reactor. The Company is constructing and will own the fuel facility.
Under the Company’s separate agreement with Dow, certain costs incurred by Dow related to the demonstrator reactor are funded by the Company using funds obtained through the ARDP. The Company has recognized the funds received from the DoE and the costs incurred by Dow on a gross basis as grant income and direct costs, respectively. The Company has recognized $5.0 million and $4.0 million as grant income and $4.3 million and $3.4 million as direct costs during the nine months ended September 30, 2025 and 2024, respectively related to costs incurred by Dow for the demonstrator reactor. The Company also earns revenue from Dow as a customer for certain site specific engineering, permitting, and other services related to the demonstrator reactor. Refer to Note 13 — Related Party Transactions.
Disaggregated Revenues and Grant Income
A summary of revenues and grant income by customer type is as follows for the nine months ended September 30, 2025 and 2024 (in thousands):
| | | |
Nine Months Ended
September 30, |
| |||||||||
| | | |
2025
|
| |
2024
|
| ||||||
| Customer Type: | | | | | | | | | | | | | |
| DoE(1) | | | | $ | 56,257 | | | | | $ | 55,862 | | |
|
DoD
|
| | | | 4,307 | | | | | | 7,934 | | |
|
Commercial
|
| | | | 12,171 | | | | | | 22,192 | | |
|
Total Revenues and Grant Income
|
| | | $ | 72,735 | | | | | $ | 85,988 | | |
(1)
For the nine months ended September 30, 2025, $44.0 million from the DOE amount is classified as services revenue and $12.3 million is classified as grant income. For the nine months ended September 30, 2024, $30.2 million from the DOE amount is classified as services revenue and $25.7 million is classified as grant income.
F-46
A summary of revenues and grant income by contract type is as follows for the nine months ended September 30, 2025 and 2024 (in thousands):
| | | |
Nine Months Ended
September 30, |
| |||||||||
| | | |
2025
|
| |
2024
|
| ||||||
| Contract Type: | | | | | | | | | | | | | |
| Cost-based(1) | | | | $ | 62,576 | | | | | $ | 74,531 | | |
|
Fixed Fee
|
| | | | 4,417 | | | | | | 1,941 | | |
|
Cost plus Fixed Fee
|
| | | | 4,783 | | | | | | 8,975 | | |
|
Time & Materials
|
| | | | 959 | | | | | | 541 | | |
|
Total Revenues and Grant Income
|
| | | $ | 72,735 | | | | | $ | 85,988 | | |
(1)
For the nine months ended September 30, 2025, $50.3 million of the cost-based contracts amount is classified as services revenue and $12.3 million is classified as grant income. For the nine months ended September 30, 2024 $48.8 million of the cost-based contracts amount is classified as services revenue and $25.7 million is classified as grant income.
Revenues and Grant Income by Geographic Location
The Company has revenues and grant income in the following countries for the nine months ended September 30, 2025 and 2024 (in thousands):
| | | |
Nine Months Ended
September 30, |
| |||||||||
| | | |
2025
|
| |
2024
|
| ||||||
| Customer Location: | | | | | | | | | | | | | |
|
United States
|
| | | $ | 71,885 | | | | | $ | 84,867 | | |
| Non-U.S.: | | | | | | | | | | | | | |
|
Canada
|
| | | | 69 | | | | | | 467 | | |
|
United Kingdom
|
| | | | 781 | | | | | | 654 | | |
|
Total Non-U.S.
|
| | | | 850 | | | | | | 1,121 | | |
|
Total Revenues and Grant Income
|
| | | $ | 72,735 | | | | | $ | 85,988 | | |
Contract Balances
The timing of revenue recognition, billings, and cash collections results in billed accounts receivable, unbilled receivables and contract assets (including amounts billable where the right to consideration is unconditional and contract assets for which government approval is required before billing can occur), and contract liabilities (customer advances and deposits) on the condensed consolidated balance sheets. Amounts are billed as work progresses in accordance with agreed-upon contractual terms, either at periodic intervals (e.g., biweekly or monthly) or upon achievement of contractual milestones. Generally, billing occurs subsequent to revenue recognition, resulting in unbilled receivables. However, the Company sometimes receives advances or deposits from its customers, before revenue is recognized, resulting in contract liabilities. These liabilities are reported on the condensed consolidated balance sheets on a contract-by-contract basis at the end of each reporting period.
Contract liabilities as of September 30, 2025 and December 31, 2024 include deferred revenue. As of September 30, 2025, the Company has deferred revenue of $1.3 million, of which $0.4 million is recorded within accrued liabilities and $0.9 million is recorded within due to related parties. As of December 31, 2024, the Company has deferred revenue of $1.1 million recorded within accrued liabilities.
Contract assets represent revenue recognized that exceeds the amount billed to the customer and excludes amounts billable where the right to consideration is solely subject to the passage of time. As of September 30,
F-47
2025, the Company has contract assets of $9.4 million, of which $7.7 million is recorded within unbilled receivables and $1.7 million is recorded within due from related parties. As of December 31, 2024, the Company has contract assets of $9.5 million, of which $7.6 million is recorded within unbilled receivables and $1.9 million is recorded within due from related parties. The change in contract assets during 2025 is immaterial.
Remaining Performance Obligation
Remaining performance obligations represent non-cancelable contracted revenue that has not yet been recognized and will be recognized as revenue in future periods. The Company has elected to apply the exemption for the disclosure of remaining performance obligations as the Company’s contracts are one year or less in duration.
NOTE 4 — PROPERTY AND EQUIPMENT, NET
Property and equipment, net consists of the following as of September 30, 2025 and December 31, 2024 (in thousands):
| | | |
September 30,
2025 |
| |
December 31,
2024 |
| ||||||
|
Equipment and materials
|
| | | $ | 2,335 | | | | | $ | 2,335 | | |
|
Computer equipment and software
|
| | | | 3,751 | | | | | | 1,131 | | |
|
Office furniture and fixtures
|
| | | | 331 | | | | | | 302 | | |
|
Leasehold improvements
|
| | | | 2,523 | | | | | | 2,480 | | |
| Land | | | | | 390 | | | | | | — | | |
|
Construction-in-progress
|
| | | | 31,027 | | | | | | 1,778 | | |
|
Property and equipment at cost
|
| | | | 40,357 | | | | | | 8,026 | | |
|
Less: accumulated depreciation
|
| | | | (3,125) | | | | | | (2,198) | | |
|
Property and equipment, net
|
| | | $ | 37,232 | | | | | $ | 5,828 | | |
All of the Company’s property and equipment is located within the United States.
No impairment losses were recognized for the nine months ended September 30, 2025 and 2024.
NOTE 5 — GOVERNMENT GRANTS FOR PROPERTY AND EQUIPMENT
During the nine months ended September 30, 2025 and 2024, the Company received reimbursements from the DoE under the ARDP related to construction of its nuclear fuel fabrication facility. During the nine months ended September 30, 2025, the Company also received reimbursements from the DoE under the ARDP related to the purchase of a building for its helium test facility. The Company recognizes the grants from the DoE at the time in which the costs are incurred in compliance with the conditions of the grant, which were $52.6 million and zero for the nine months ended September 30, 2025 and 2024, respectively.
F-48
NOTE 6 — ACCRUED LIABILITIES
The following table sets forth the components of accrued liabilities as of September 30, 2025 and December 31, 2024 (in thousands):
| | | |
September 30,
2025 |
| |
December 31,
2024 |
| ||||||
|
Operating lease liabilities
|
| | | $ | 3,486 | | | | | $ | 2,486 | | |
|
Accrued payroll and related expenses
|
| | | | 14,704 | | | | | | 13,336 | | |
|
Accrued subcontractor costs
|
| | | | 16,148 | | | | | | 17,331 | | |
|
Accrued transaction costs
|
| | | | 1,485 | | | | | | 354 | | |
|
Deferred revenue
|
| | | | 468 | | | | | | 306 | | |
|
Incurred cost audits reserve (Note 14)
|
| | | | 1,068 | | | | | | — | | |
|
Accrued professional fees
|
| | | | 2,638 | | | | | | 954 | | |
|
Accrued liabilities – other
|
| | | | 358 | | | | | | 612 | | |
|
Total accrued liabilities
|
| | | $ | 40,356 | | | | | $ | 35,379 | | |
NOTE 7 — DEBT
The following table summarizes the Company’s outstanding debt as of September 30, 2025 and December 31, 2024 (in thousands):
| | | |
September 30,
2025 |
| |
December 31,
2024 |
| ||||||
|
C-2 Notes
|
| | | | — | | | | | $ | 18,357 | | |
|
Total
|
| | | | — | | | | | $ | 18,357 | | |
|
Less: short-term borrowings
|
| | | | — | | | | | | (18,357) | | |
|
Total long-term obligations
|
| | | | — | | | | | | — | | |
No debt was outstanding at September 30, 2025. The fair value of the C-2 Notes outstanding as of December 31, 2024 equates to carrying value as the Company elected to apply the fair value option to the measurement of the C-2 Notes.
Live Oak Credit Facility
On June 14, 2021, the Company and one of the Company’s subsidiaries entered into a credit agreement for a revolving credit facility (the “Live Oak Credit Facility”) with Live Oak Bank.
The borrowing base was limited to a set percentage of eligible accounts, less reserves that may be established by the lender in the exercise of their reasonable credit judgment. In connection with the credit agreement, the Company incurred lender and third-party fees. Additionally, a commitment fee was accrued on any unused portion of the commitments under the Live Oak Credit Facility during the preceding three calendar month period. The commitment fee was 0.25% applied to the difference between the revolving commitment and the average daily outstanding balance for each quarter. The lender and third-party fees and commitment fees were immaterial for the nine months ended September 30, 2025 and 2024.
The obligations under the Live Oak Credit Facility were guaranteed by the Company and its wholly owned domestic subsidiaries. The obligations under the Live Oak Credit Facility were secured by a first priority security interest in substantially all of the equipment, accounts receivable, investment property and general intangibles and all proceeds and products thereof, as well as 100% of the common equity interests of the present and subsequently acquired domestic subsidiaries of the Company. The Live Oak Credit Facility was permitted to be voluntarily prepaid in whole, or in part, in each case without premium or penalty. The Company was also required to make mandatory prepayments when (a) the aggregate borrowings exceed the lesser of the (i) revolving commitment and (ii) the available borrowing base or (b) certain events of default have occurred and were continuing.
F-49
The Live Oak Credit Facility carried an interest rate based on a floating rate indexed to the Prime rate plus 1.0%, subject to a 4% floor. The average interest rate in effect under the Live Oak Credit Facility was 9.5% for the nine months ended September 30, 2024. Interest expense associated with this credit facility for the nine months ended September 30, 2024 was $0.4 million.
In accordance with the Live Oak Credit Facility’s stated terms, the Company settled the outstanding principal associated with the Live Oak Credit Facility in October 2024. On October 31, 2024, with no outstanding borrowings, the facility matured. On May 9, 2025, the Company reestablished the facility, with a capacity of $20.0 million and an expiration date of December 1, 2025. There have been no draws on the facility during the nine months ended September 30, 2025. Subsequent to September 30, 2025, with no outstanding borrowings, the facility matured.
C-1 Convertible Notes
In 2022, the Company issued a series of convertible promissory notes (“C-1 Notes”) in the aggregate principal amount of $57.4 million with an annual interest rate of 7.00%. Of the $57.4 million in principal, $37.4 million was due on March 31, 2024 and $20.0 million was due on October 7, 2024 to a related party.
The C-1 Notes contained embedded derivatives which, absent the election of the fair value option, would have been bifurcated and accounted for at fair value. Accordingly, the fair value option was elected for the C-1 Notes at issuance.
On March 29, 2024, the remaining $20.0 million principal outstanding on the C-1 Notes converted into 3,210,405 Series C Preferred Units (the “C-1 Conversion”). Since the C-1 Notes were historically accounted for by applying the fair value option, in accordance with ASC 825-10, Financial Instruments — Overall (“ASC 825-10”), the Company included in net loss the $1.3 million cumulative gain previously recorded in other comprehensive income (loss) for the extinguished C-1 Notes that resulted from changes in instrument-specific credit risk.
C-2 Convertible Notes
In 2022 and 2023, the Company issued convertible notes payable in an aggregate principal amount of $28.0 million and $85.0 million (“C-2 Notes”), respectively, of which $70.0 million of the C-2 Notes were issued to related parties. The C-2 Notes were scheduled to mature on September 30, 2025 and accrue 10.0% of payable-in-kind interest annually.
The C-2 Notes contained embedded derivatives which, absent the election of the fair value option, would have been bifurcated and accounted for at fair value. Accordingly, the fair value option was elected for the C-2 Notes at issuance.
On October 11, 2024, certain of the C-2 Notes with an aggregate principal balance of $98.0 million converted into 16,960,021 Series C Preferred Units, which was accounted for as a debt extinguishment. As of December 31, 2024, the outstanding principal, inclusive of payable-in-kind interest, on the C-2 Notes was $18.4 million and the fair value was $18.5 million, resulting in a cumulative loss of $0.1 million.
On September 30, 2025, the outstanding principal and unpaid accrued interest on the C-2 Note were converted into 2,870,172 Series C Preferred Units, resulting in the extinguishment of the C-2 Note. Therefore, as of September 30, 2025, there was no outstanding principal on the C-2 Notes, and the cumulative loss recognized on the C-2 Notes was $4.0 million, which was recorded in other expense, net in the condensed consolidated statements of operations. Further, since the C-2 Notes were historically accounted for by applying the fair value option, in accordance with ASC 825-10, the Company included in net loss of the $0.3 million cumulative loss previously recorded in other comprehensive income (loss) for the extinguished C-2 Notes that resulted from changes in instrument-specific credit risk.
2023 Bridge Loan
On October 4, 2023, the Company entered into a credit agreement (the “2023 Bridge Loan”) with a related party, Ares Acquisition Holdings, LP for a $10.0 million term loan. In addition, subject to the mutual agreement of Ares Acquisition Holdings, LP, additional draws of up to $10.0 million per calendar month.
F-50
The Company assessed the terms of the 2023 Bridge Loan in order to identify embedded features and determine if any such features should be bifurcated and accounted for separately as derivative. The Company determined that the event of default interest rate adjustment feature, event of default redemption feature, and contingent additional interest feature required bifurcation and separate accounting as derivative liabilities. Accordingly, the bifurcated embedded derivatives were recorded at fair value upon issuance of each relevant draw and were subsequently remeasured at the end of each reporting period. The bifurcated embedded derivatives that were created upon new draws resulted in a discount on the 2023 Bridge Loan which was subsequently amortized over the life of the 2023 Bridge Loan through periodic charges to interest expense.
During Q2 and Q3 2024, the Company entered into a series of amendments to the 2023 Bridge Loan, which, among other things, extended the maturity date to March 26, 2025. The Company concluded that each of the amendments to the 2023 Bridge Loan constituted, for accounting purposes, debt extinguishments.
During the nine months ended September 30, 2024, the Company recorded $4.2 million in interest expense related to the amortization of the discount created by embedded derivatives. Additionally, new embedded derivatives, with a total fair value of $2.7 million, were recorded as a part of amendments to the 2023 Bridge Loan during the nine months ended September 30, 2024. The Company determined the fair value of the embedded derivatives by considering the probability of the settlement of the feature, its settlement value, and other assumptions. See Note 13 — Fair Value Measurements for further information.
On October 11, 2024, in accordance with the 2023 Bridge Loan’s stated terms, the Company paid the outstanding principal and interest on the 2023 Bridge Loan of $53.5 million, and the 2023 Bridge Loan was settled. The settlement has been accounted for as an extinguishment of the 2023 Bridge Loan.
2024 Convertible Note
On September 26, 2024, the Company entered into a convertible note with Amazon.com NV Investment Holdings LLC in the principal amount of $20.0 million (the “2024 Convertible Note”). While outstanding, the debt accrued paid-in-kind interest of 12% per annum, compounded quarterly. Interest expense recognized related to the 2024 Convertible Note was immaterial through September 30, 2024. On October 11, 2024, in conjunction with the Series C-1 Preferred Units financing discussed below and in accordance with the 2024 Convertible Note’s stated terms, the outstanding principal and interest of the 2024 Convertible Note of $20.1 million was converted into 3,097,477 Series C-1 Preferred Units (“2024 Convertible Note Conversion”). Since the 2024 Convertible Note was converted via the creditor’s exercise of its unit-settled redemption right, the conversion was accounted for as a debt extinguishment and no balance remained outstanding at December 31, 2024.
2024 Bridge Loan
On September 26, 2024, the Company entered into a bridge loan with Escape2, LLC, an entity affiliated with an investor (the “2024 Bridge Loan”), in the amount of $3.8 million. While outstanding, the 2024 Bridge Loan accrued paid-in-kind interest of 12% per annum, compounded quarterly and had a maturity date of March 26, 2025, or upon the receipt of a third-party investment with aggregate net cash proceeds of at least $100.0 million, if such an investment occurs prior to the maturity date. On October 11, 2024, in accordance with its stated terms, the 2024 Bridge Loan was automatically redeemed, and the Company paid the outstanding principal and interest associated with the 2024 Bridge Loan of $3.8 million.
Bank of New York Credit Facility
On July 28, 2020, the Company executed a credit agreement with Pershing LLC, an affiliate of Bank of New York Mellon, in the form of a revolving credit facility (the “Bank of New York Credit Facility”), which was subject to the guarantee by GM LLC and Ghaffarian Enterprises LLC (collectively, “Ghaffarian”), who represented related party investors.
During the year ended December 31, 2024, the Company entered into Credit Support Fee and Subrogation Agreements (the “2024 Credit Support Fee Agreements”) with Ghaffarian , which increased the availability under the Bank of New York Credit Facility to $20.0 million and extended the maturity of the
F-51
credit support to March 26, 2025. In conjunction with the 2024 Credit Support Fee Agreements, the Company agreed to pay Ghaffarian a monthly 12% credit support fee to be paid in- kind.
Borrowings under the Bank of New York Credit Facility bear interest at the Federal Funds rate, subject to a 0.25% floor, plus a margin. For borrowings, the applicable rate margin is 0.90%. The proceeds of loans under the agreement are available for working capital needs, permitted acquisitions and other general corporate purposes. The average interest rate in effect under the Bank of New York Credit Facility was 6.4% for the nine months ended September 30, 2024. For the nine months ended September 30, 2024, interest expense associated with the Bank of New York Credit Facility was $0.4 million.
On October 11, 2024, in accordance with the facility’s stated terms, the Company settled the outstanding principal and interest associated with the Bank of New York Credit Facility with a payment of $20.2 million, and the 2024 Credit Support Fee Agreements were terminated. The Bank of New York Credit Facility did not have an outstanding balance as of December 31, 2024, and the facility matured with no balance on March 26, 2025.
NOTE 8 — LEASES
Lease balances as of September 30, 2025 and December 31, 2024 are as follows (in thousands):
| | | |
September 30,
2025 |
| |
December 31,
2024 |
| ||||||
|
Operating lease ROU assets
|
| | | $ | 22,756 | | | | | $ | 11,003 | | |
|
Current portion of operating lease liabilities
|
| | | | 3,486 | | | | | | 2,486 | | |
|
Long-term portion of operating lease liabilities
|
| | | | 19,012 | | | | | | 10,338 | | |
|
Total operating lease liabilities
|
| | | $ | 22,498 | | | | | $ | 12,824 | | |
The current portion of operating lease liabilities is reflected within accrued liabilities on the condensed consolidated balance sheets.
Operating Leases
The Company leases office spaces, which have initial operating lease terms of three to twelve years. Some leases have options to extend the lease term, ranging from six months to six years. Certain leases have early termination options, which the Company is not reasonably certain to exercise.
During 2024, the Company modified certain existing leases to extend lease terms, ranging from approximately six months to two years. During the nine months ended September 30, 2025, the Company modified one existing operating lease to extend the lease term and increase the leased premises. The Company separately exercised an early termination option on another operating lease to reduce its lease term. These actions resulted in two distinct modifications to the Company’s operating leases during the period.
Additionally, during the nine months ended September 30, 2025, the Company entered into a lease agreement for corporate office space, with a lease term of twelve years commencing in August 2025. The lease agreement includes a $3.9 million standby letter of credit, of which $3.5 million is classified as restricted cash on the condensed consolidated balance sheet, which is not considered a lease payment and is excluded from the measurement of the right-of-use (“ROU”) asset and lease liability. The lease agreement also includes $17.1 million in lease incentives, of which the lessor has provided a $14.7 million tenant improvement allowance, which is treated as a lease incentive for lessee-owned improvements. The lease incentives reduce the right-of-use asset and lease liability recognized at lease commencement as the Company is reasonably certain to receive the lease incentives.
Operating lease cost totaled $4.1 million and $3.5 million for the nine months ended September 30, 2025 and 2024, respectively, and was recognized on a straight-line basis over the lease term. Variable lease expenses and short-term lease expenses were immaterial for the nine months ended September 30, 2025 and 2024.
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Future minimum lease payments under operating leases as of September 30, 2025 are as follows (in thousands):
| | | |
Operating
Leases |
| |||
|
2025
|
| | | $ | 1,525 | | |
|
2026
|
| | | | 4,831 | | |
|
2027
|
| | | | 4,121 | | |
|
2028
|
| | | | 4,737 | | |
|
2029
|
| | | | 6,008 | | |
|
Thereafter
|
| | | | 44,460 | | |
|
Total minimum lease payments
|
| | | $ | 65,682 | | |
|
Less: lease incentives
|
| | | | (17,092) | | |
|
Less: amounts representing interest or imputed interest
|
| | | | (26,092) | | |
|
Present value of lease obligations
|
| | | $ | 22,498 | | |
Supplemental cash flow information for the nine months ended September 30, 2025 and 2024 relating to the Company’s leases is as follows (in thousands):
| | | |
September 30,
|
| |||||||||
| | | |
2025
|
| |
2024
|
| ||||||
|
Operating cash flows used in operating leases
|
| | | $ | 6,090 | | | | | $ | 2,090 | | |
| Non-Cash Items: | | | | | | | | | | | | | |
|
Change to ROU asset and lease liability due to lease modifications and reassessments
|
| | | | (3,613) | | | | | | 1,450 | | |
|
ROU assets recorded under new operating leases
|
| | | | 15,748 | | | | | | — | | |
The weighted average remaining lease term and discount rates for operating leases are as follows for the nine months ended September 30, 2025 and 2024:
| | | |
Nine Months Ended
September 30, |
| |||
| | | |
2025
|
| |
2024
|
|
|
Weighted Average Remaining Lease Term
|
| |
9.1 years
|
| |
5.2 years
|
|
|
Weighted Average Discount Rate
|
| |
10.0%
|
| |
10.0%
|
|
NOTE 9 — PROFIT SHARING PLAN
The Company maintains a defined contribution profit sharing plan (the “Plan”), which includes a salary deferral arrangement, under the provisions of Section 401(k) of the Internal Revenue Code. Employees are eligible to participate in the Plan on the date of employment. Employees may contribute up to 100% of annual compensation limited to Internal Revenue Code Service maximums. The Company matches 100% of employees’ contributions up to 4% of annual compensation. The Company contributed $3.1 million and $2.2 million to the Plan during the nine months ended September 30, 2025 and 2024, respectively.
NOTE 10 — MEMBER UNITS AND PREFERRED UNITS
Series C Preferred Units
On September 30, 2025, the Company’s C-2 Note was converted into 2,870,172 Series C Preferred Units. The Series C Preferred Units issued as a result of this transaction were recognized at fair market value.
Refer to Note 7 — Debt for further discussion on the convertible note conversion.
F-53
Series C-1 Preferred Units
On January 24, 2025, the Company completed additional financing rounds of Series C-1 Preferred Units, receiving gross cash proceeds of approximately $53.4 million from various investors. As a result of this financing round, the Company issued 8,235,521 Series C-1 Preferred Units.
Preferred Units
Together, the Series A Preferred Units, the Series A-1 Preferred Units, the Series B Preferred Units, the Series C Preferred Units, and the Series C-1 Preferred Units shall be referred to as the “Preferred Units” for the purpose of this Note. Preferred Units have been issued in one or more series, each of such series consisting of such number of units and to have such terms, rights, powers and preferences, and the qualifications and limitation with respect thereto, as stated or expressed in the original or amended Certificate of Incorporation.
Optional Conversion Feature
Each Preferred Unit is convertible, at the option of the holder thereof, at any time, and without the payment of additional consideration by the holder thereof, into an equal number of Class A Common Units as is determined by dividing the Original Issue Price, initially (i) $0.5754 per Unit for each Series A Preferred Unit, (ii) $7.6348 for each Series A-1 Preferred Unit, (iii) $9.1162 per Unit for each Series B Preferred Unit, (iv) $7.6348 per Unit for each Series C Preferred Unit, and (v) $6.487 per Unit for each Series C-1 Preferred Unit, for the series of preferred units by the conversion price, initially equal to the applicable original issue price per unit, of such series of Preferred Units in effect at the time of conversion. Outstanding Preferred Units are therefore convertible into the following quantities of Class A Common Units as of September 30, 2025: 90,625,588 relating to Series A Preferred Units, 8,808,351 relating to Series A-1 Preferred Units, 11,643,171 relating to Series B Preferred Units, 39,963,592 relating to Series C Preferred Units, and 107,908,114 relating to Series C-1 Preferred Units. Conversion may be effected at any time at the sole discretion of the holder.
Cumulative Preferred Return
The Preferred Units have an annual 3% cumulative preferred return on the original issuance price, beginning on the date such Preferred Units were issued. As of September 30, 2025, the accumulated preferred return not reflected in the condensed consolidated balance sheet for Series A, A-1, B, C, and C-1 Preferred Units was $6.6 million, $3.7 million, $13.3 million, $11.9 million, and $19.1 million, respectively. As of December 31, 2024, the accumulated preferred return not reflected in the condensed consolidated balance sheet for Series A, A-1, B, C, and C-1 Preferred Units was $5.4 million, $2.2 million, $10.9 million, $5.5 million and $3.5 million, respectively. In the event of a deemed liquidation, the cumulative preferred return is payable solely for the Series B Preferred Units and therefore has been incorporated into the Series B Preferred Units liquidation preference amount presented on the balance sheet. The cumulative preferred return on the remaining units is subject to discretion of the Board of Directors.
Liquidation Preference
In the event of any liquidation, dissolution, or winding up of the Company, or a deemed liquidation event, including a merger or consolidation, or a sale or other disposition of all or substantially all of the Company’s assets, the holders shall receive distributions in an amount up to their liquidation preference. See the condensed consolidated balance sheet for the liquidation preference amounts. The preference of distributions is first to Series C-1 Preferred Unit holders, second to Series C Preferred Unit holders, third to Series B Preferred Units holders, fourth to Series A and Series A-1 Preferred Units holders, fifth to Class B-1 Profits Interest Units, until members have received cumulative distributions equal to approximately $9.5 million. After the payment of the full liquidation preference of the redeemable convertible preferred stock and profits interests, the Company’s remaining assets legally available for distribution, if any, would be distributed ratably to the holders of Class A and Class B Common Units.
Classification
A redeemable equity security is to be classified as temporary or mezzanine equity if it is conditionally redeemable upon the occurrence of an event that is not solely within the control of the issuer.
F-54
The Preferred Units and Common Units are redeemable for cash upon the occurrence of a deemed liquidation event. As of September 30, 2025 and December 31, 2024, a deemed liquidation event is not considered probable, and the occurrence of such an event is considered to be outside of the Company’s control. Accordingly, the Preferred Units and Common Units are considered conditionally redeemable upon the occurrence of an event that is not solely within the control of the issuer and, therefore, the Company has classified the Preferred Units and Common Units as mezzanine equity in the condensed consolidated balance sheets as of September 30, 2025 and December 31, 2024. The mezzanine equity amount related to Common Units issued as unit-based compensation is the grant date redemption value, or the modification date redemption value, as applicable. The difference between the grant date fair value and the redemption value for vested awards is presented in additional paid-in capital if the grant date fair value exceeds the redemption value, or accumulated deficit if the grant date fair value is less than the redemption value on the condensed consolidated balance sheets. As of September 30, 2025 and December 31, 2024, $74.5 million and $72.4 million, respectively, has been presented within mezzanine equity, and the excess of redemption value over grant date fair value for vested awards has been recorded within accumulated deficit on the condensed consolidated balance sheets. Additionally, the Company does not believe that related contingent events and the redemption of the Class B Common Units is probable to occur.
NOTE 11 — UNIT-BASED COMPENSATION EXPENSE
During the nine months ended September 30, 2025, under the Company’s 2022 long-term incentive plan, the Company granted 10,266,000 additional Class B-2 units, with an aggregate fair value of $22.5 million, with some of the awards vesting upon the grant, and a two year sale restriction in addition to existing equity transfer restrictions in the Limited Liability Agreement. The fair value of the awards is based on a Black-Scholes model and requires significant judgements and use of estimates, particularly with regard to time to exit and volatility. Volatility is determined by reference to the actual volatility of several publicly traded companies that are similar to the Company in its industry sector.
Unit-based compensation expense of $9.1 million was classified as selling, general, and administrative expense, $1.5 million was classified as a direct expense, and $0.3 million was capitalized into property and equipment as part of the Company’s fuel facility construction project for the nine months ended September 30, 2025. Unit-based compensation expense of $0.9 million was classified as selling, general, and administrative expense and $0.1 million was classified as a direct expense for the nine months ended September 30, 2024. The total fair value of units that vested during the nine months ended September 30, 2025 and 2024 was $5.5 million and $0.9 million, respectively. As of September 30, 2025, the Company had $11.3 million of unrecognized unit-based compensation that is expected to be recognized over a weighted average period of 1.9 years.
NOTE 12 — FAIR VALUE MEASUREMENTS
The liabilities recorded at fair value and measured on a recurring basis are all Level 3 measurements as of September 30, 2025 and December 31, 2024.
Rollforward of Level 3 Measurements
A roll forward of the Level 3 measurements as for the nine-months ended September 30, 2025 and September 30, 2024 are as follows:
F-55
| | | |
June
2022 Warrants |
| |
October
2022 Warrants |
| |
December
2022 Warrants |
| |
C-1 Notes
|
| |
C-2 Notes
|
| |
2024
Warrants |
| |
2024
Financial Instrument |
| |
Embedded
Derivatives |
| ||||||||||||||||||||||||
|
Beginning Balance as of January 1, 2024
|
| | | $ | 3,082 | | | | | $ | 4,450 | | | | | $ | 912 | | | | | $ | 25,901 | | | | | $ | 121,240 | | | | | | — | | | | | | — | | | | | $ | 6,153 | | |
|
Exercises/Settlements
|
| | | | — | | | | | | (5,175) | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | |
|
Conversions
|
| | | | — | | | | | | — | | | | | | — | | | | | | (27,138) | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | |
|
Issuances
|
| | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | 12,266 | | | | | | 3,912 | | |
|
Change in Fair Value recognized in other expense, net
|
| | | | 852 | | | | | | 725 | | | | | | 467 | | | | | | 1,237 | | | | | | 7,041 | | | | | | — | | | | | | (12,266) | | | | | | (10,065) | | |
|
Change in Far Value attributable to
instrument-specific credit risk recognized in other comprehensive income(1) |
| | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | 6,396 | | | | | | — | | | | | | — | | | | | | — | | |
|
Ending Balance as of September 30, 2024
|
| | | $ | 3,934 | | | | | | — | | | | | $ | 1,379 | | | | | | — | | | | | $ | 134,677 | | | | | | — | | | | | | — | | | | | | — | | |
|
Beginning Balance as of January 1, 2025
|
| | | | 3,636 | | | | | | — | | | | | | 1,394 | | | | | | — | | | | | | 18,537 | | | | | | 45,604 | | | | | | — | | | | | | — | | |
|
Conversions
|
| | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | (30,787) | | | | | | — | | | | | | — | | | | | | — | | |
|
Change in Fair Value recognized in other expense, net
|
| | | | 6,615 | | | | | | — | | | | | | (1,394) | | | | | | — | | | | | | 12,694 | | | | | | 200,765 | | | | | | — | | | | | | — | | |
|
Change in Far Value attributable to
instrument-specific credit risk recognized in other comprehensive income(1) |
| | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | | (444) | | | | | | — | | | | | | — | | | | | | — | | |
|
Ending Balance as of September 30, 2025
|
| | | $ | 10,251 | | | | | | — | | | | | | — | | | | | | — | | | | | | — | | | | | $ | 246,369 | | | | | | — | | | | | | — | | |
(1)
As the fair value option is elected for the C-1 Notes and C-2 Notes, the change in fair value attributable to instrument- specific credit risk associated with each instrument is recorded within other comprehensive income or loss. The remaining change in fair value is recorded within other expense, net on the condensed consolidated statements of operations and comprehensive loss. The change in instrument specific credit risk is estimated based on the option adjusted spread of comparable companies and the option adjusted spread of the US high yield index for companies with similar credit ratings.
Valuation Techniques and Significant Unobservable Inputs
A significant increase or decrease in any of the significant unobservable inputs used in the fair value measurement of the warrant liabilities, derivative liability, C-1 Notes, or C-2 Notes could result in a significantly higher or lower fair value measurement. The quantitative inputs and assumptions used for items categorized in Level III of the fair value hierarchy as of September 30, 2025 and December 31, 2024 are summarized below:
2024 Warrants
The fair value of the 2024 Warrants is based on an option pricing model. The range of significant inputs, including significant unobservable inputs, used in the recurring Level 3 fair value measurements of the 2024 Warrants as of September 30, 2025 and December 31, 2024 are as follows:
|
Significant Inputs
|
| |
September 30,
2025 |
| |
December 31,
2024 |
|
|
Expected term (years)
|
| |
0.3 – 0.5
|
| |
1.3
|
|
|
Equity volatility
|
| |
74.6 – 90.0%
|
| |
58.0%
|
|
|
Risk-free rate
|
| |
3.8 – 4.0%
|
| |
4.1%
|
|
June 2022 Warrants
In conjunction with a guarantee to the Bank of New York Credit Facility, the Company issued $10.0 million of warrants (the “June 2022 Warrants”) to Ghaffarian on June 30, 2022. The fair value of the June 2022 Warrants is based on an option pricing model. The significant inputs, including significant
F-56
unobservable inputs, used in the recurring Level 3 fair value measurements of the June 2022 Warrants as of September 30, 2025 and December 31, 2024, are as follows:
|
Significant Inputs
|
| |
September 30,
2025 |
| |
December 31,
2024 |
|
|
Expected term (years)
|
| |
0.3 – 2.4
|
| |
3.2
|
|
|
Equity volatility
|
| |
90.0 – 94.8%
|
| |
63.0%
|
|
|
Risk-free rate
|
| |
3.6 – 4.0%
|
| |
4.2%
|
|
December 2022 Warrants
On December 5, 2022, the Company issued 444,444 warrants (the “December 2022 Warrants”) to purchase common units of the Company. The December 2022 Warrants have an exercise price of $0.01 per unit and are not exercisable until 36 months following the issuance of the C-2 Notes, subject to the achievement of certain business requirements. As of September 30, 2025, the achievement of the business requirements was deemed not probable and the fair value was marked to zero. The December 2022 Warrants were freestanding financial instruments and are liability classified as of December 31, 2024. The fair value is determined based on an option pricing model using the contractual strike price. The significant inputs, including significant unobservable inputs, used in the recurring Level 3 fair value measurements of the December 2022 Warrants as of December 31, 2024 are as follows:
|
Significant Inputs
|
| |
December 31,
2024 |
|
|
Expected term (years)
|
| |
3.2
|
|
|
Equity volatility
|
| |
63.0%
|
|
|
Risk-free rate
|
| |
4.2%
|
|
C-2 Notes
For the year ended December 31, 2024, the fair value of the C-2 Notes is based on a binomial lattice model. On September 30, 2025, the C-2 Notes converted into equity. Refer to Note 7 — Debt for further discussion on the convertible note conversion. The fair value immediately prior to conversion was estimated using the value of the underlying conversion shares. The significant inputs, including significant unobservable inputs, used in the recurring Level 3 fair value measurements of the C-2 Notes as of September 30, 2025 and December 31, 2024 are as follows:
|
Significant Inputs
|
| |
September 30,
2025 |
| |
December 31,
2024 |
| ||||||
|
Discount rate
|
| | | | N/A | | | | | | 14.2% | | |
|
Credit Spread
|
| | | | N/A | | | | | | 10.0% | | |
|
Equity Volatility
|
| | | | 85.0% | | | | | | 56.0% | | |
|
Risk-free rate
|
| | | | 3.6% | | | | | | 4.2% | | |
NOTE 13 — RELATED PARTY TRANSACTIONS
In the ordinary course of business, the Company enters into transactions with various related parties.
Related Party Revenue
Dow is a unitholder and warrantholder of XERC. In 2025, the Company entered into an agreement with Dow, which is a continuation of the project under the previously existing joint development agreement with Dow entered into in 2024. Additionally, during the nine months ended September 30, 2024, the Company entered into a project with a separate related party to provide design and engineering services. The table below
F-57
summarizes related party revenues that are reflected within services revenue in the condensed consolidated statements of operations and comprehensive loss for the nine months ended September 30, 2025 and 2024 (in thousands):
| | | |
Nine Months Ended
September 30, |
| |||||||||
| | | |
2025
|
| |
2024
|
| ||||||
|
Revenue associated with Dow
|
| | | $ | 6,320 | | | | | $ | 18,673 | | |
|
Revenue associated with design and engineering services
|
| | | | — | | | | | | 584 | | |
|
Total
|
| | | $ | 6,320 | | | | | $ | 19,257 | | |
Related Party Expenses
The Company enters into various arrangements with related party vendors. These arrangements primarily include subcontracting services and general and administrative services, as well as a credit support fee. For subcontracting services, the Company engages with Hatch Associate Consultants, Inc (“Hatch”), Aerotherm, Inc. (“Aerotherm”), Zachry Nuclear Engineering, Inc. (“Zachry”), Burns & McDonnell Engineering Company, Inc. (“Burns & McDonnell”), Dow, and Curtiss-Wright Corporation (“Curtiss-Wright”). For general and administrative services, the Company engages with IBX, LLC (“IBX”) and IBX 801 Thompson Realty, LLC (“IBX Thompson”). Credit support fees are incurred to Ghaffarian. Hatch, Zachry, Burns & McDonnell, Dow, and Curtiss-Wright are investors of the Company, Aerotherm shares a common member of management with the Company, and IBX, IBX Thompson, and Ghaffarian are owned by the chairman of the board of directors of the Company.
The subcontracting services primarily pertain to support services related to ARDP, and the general and administrative services include rent for office space, consulting services, and other general and administrative services. The credit support fee relates to the Bank of New York Credit Facility described above in Note 7 — Debt. The table below summarizes the expenses with related parties that are reflected in the condensed consolidated statement of operations and comprehensive loss for these categories for the nine months ended September 30, 2025 and 2024 (in thousands):
| | | |
Nine Months Ended
September 30, |
| |||||||||
| | | |
2025
|
| |
2024
|
| ||||||
|
Subcontracting services(1)
|
| | | $ | 14,851 | | | | | $ | 19,932 | | |
|
General and administrative services(2)
|
| | | | 718 | | | | | | 2,226 | | |
|
Credit support fee(3)
|
| | | | — | | | | | | 840 | | |
|
Total
|
| | | $ | 15,569 | | | | | $ | 22,998 | | |
(1)
Expenses relating to subcontracting services are reflected within direct costs in the condensed consolidated statements of operations and comprehensive loss.
(2)
Expenses related to general and administrative services are reflected within selling, general, and administrative expenses in the condensed consolidated statements of operations and comprehensive loss.
(3)
Expenses related to credit support fee are reflected within interest expense in the condensed consolidated statements of operations and comprehensive loss.
F-58
Due to/from Related Parties
As of September 30, 2025 and December 31, 2024, the following balances were recorded within due from related parties for the above projects (in thousands):
| | | |
September 30,
2025 |
| |
December 31,
2024 |
| ||||||
|
Due from related party related to Dow(1)
|
| | | $ | 4,660 | | | | | $ | 15,774 | | |
|
Other
|
| | | | 158 | | | | | | 199 | | |
|
Total
|
| | | $ | 4,818 | | | | | $ | 15,973 | | |
(1)
Of the total balance due from related party related to Dow, $4.0 million and $7.7 million is unbilled as of September 30, 2025 and December 31, 2024, respectively.
As of September 30, 2025 and December 31, 2024, the following balances were recorded within due to related parties for the above services (in thousands):
| | | |
September 30,
2025 |
| |
December 31,
2024 |
| ||||||
|
Due to related parties for subcontracting services
|
| | | $ | 3,950 | | | | | $ | 7,464 | | |
|
Due to related parties for general and administrative services
|
| | | | 109 | | | | | | 186 | | |
|
Deferred revenue with related parties
|
| | | | 866 | | | | | | 569 | | |
|
Other
|
| | | | — | | | | | | 261 | | |
|
Total
|
| | | $ | 4,925 | | | | | $ | 8,480 | | |
See Note 7 — Debt for disclosure related to debt from related parties.
NOTE 14 — COMMITMENTS AND CONTINGENCIES
Incurred Cost Audits
The Company predominantly performs contract services for the DoE. The Company’s costs incurred on such contracts with the DoE are subject to final incurred cost audits prior to the close out of the award as specified in such contracts. Billings under this contract are based on provisional rates that permit recovery of allowable overhead, and general and administrative expenses not exceeding certain limits. These rates are subject to review by the government on an annual basis. When final determination and approval of the allowable rates have been made, billings may be adjusted.
The Company is currently undergoing audits of the costs incurred through December 31, 2023. As of September 30, 2025, the Company has $1.1 million in contract-related reserves for its estimate of potential refunds to the government. As of December 31, 2024, the impact of any cost audit findings were immaterial.
Investigations and Litigation
From time to time the Company may become involved in legal proceedings or be subject to claims arising in the ordinary course of its business. The Company is not, to the best of its knowledge, presently a party to any legal proceedings that, if determined adverse to the Company, would individually or taken together have a material adverse effect on its business, operating results, financial condition, or cash flows.
F-59
NOTE 15 — SUPPLEMENTAL CASH FLOW INFORMATION
Supplemental cash flow disclosures for the nine months ended September 30, 2025 and 2024 are as follows (in thousands):
| | | |
Nine Months Ended
September 30, |
| |||||||||
| | | |
2025
|
| |
2024
|
| ||||||
|
Cash Paid for Interest
|
| | | $ | — | | | | | $ | 857 | | |
| Non-Cash Investing and Financing Activities: | | | | | | | | | | | | | |
|
Conversion of C-1 & C-2 Notes to Series C Preferred Units
|
| | | | 30,787 | | | | | | 27,138 | | |
|
Valuation of Derivative Liability
|
| | | | — | | | | | | 3,912 | | |
|
Class B Common Units related to the issuance and conversion of debt
|
| | | | — | | | | | | 9,061 | | |
|
Unpaid transaction costs
|
| | | | 1,938 | | | | | | 1,531 | | |
|
Government grant reimbursement receivable for purchase of property
and equipment |
| | | | 15,092 | | | | | | — | | |
|
Property and equipment included in accounts payable and accrued
expenses |
| | | | 5,396 | | | | | | — | | |
NOTE 16 — SEGMENTS
Under the guidelines of ASC 280, which require companies to present financial information about their operating segments, products and services, geographic regions, and significant customers, the Company’s Chief Executive Officer serves as the chief operating decision maker (“CODM”). The CODM evaluates financial performance, allocates resources, and makes strategic decisions based on the consolidated results of the Company, rather than evaluating discrete lines of business. Accordingly, management has determined that the Company comprises a single reportable segment.
In making resource allocation and assessing operational outcomes, the CODM relies on overall net income (loss) as the primary metric both during the annual planning process and for evaluating results on a quarterly basis. The primary expenses presented to the CODM and incorporated in segment performance are related to the operating expenses; direct costs, selling, general and administrative costs, and research and development costs — as well as the non-operating expenses; interest expense, interest income, and other income (expense). The condensed consolidated statements of operations for the nine months ended September 30, 2025 and 2024 present these significant segment expenses for the Company’s single operating segment. The condensed consolidated balance sheets as of September 30, 2025 and December 31, 2024 likewise display the assets and liabilities attributable to this single segment.
NOTE 17 — SUBSEQUENT EVENTS
In preparing these financial statements, the Company has evaluated subsequent events to determine if any require recognition or disclosure. Subsequent events have been evaluated through January 16, 2026, the date the financial statements were available to be issued.
2025 Warrant Issuance
In October 2025, the Company issued the 2025 Warrant to a related party to purchase up to 14,123,859 Series C-1 Preferred Units at an exercise price of $6.4870 per unit.
Series D Equity Issuance
In November 2025, the Company issued 48,134,320 and 20,635 Series D Preferred Units, respectively, and received gross cash proceeds of approximately $700.0 million.
December PIU Grant
In December 2025, the Company issued 8,230,995 additional Class B-2 performance incentive units to certain employees.
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Shares
![[MISSING IMAGE: lg_xenergy-bw.jpg]](https://cdn.kscope.io/66e241b40ec9a8be53aefe262681fd00-lg_xenergy-bw.jpg){kind=small}
X-Energy, Inc.
Class A Common Stock
PRELIMINARY PROSPECTUS
, 2026
J.P. Morgan
Until , 2026 (the 25th day after the date of this prospectus), all dealers effecting transactions in these securities, whether or not participating in this offering, may be required to deliver a prospectus. This is in addition to a dealer’s obligation to deliver a prospectus when acting as an underwriter and with respect to an unsold allotment or subscription.
PART II
INFORMATION NOT REQUIRED IN THE PROSPECTUS
Item 13. Other expenses of issuance and distribution.
The following table sets forth all fees and expenses, other than the underwriting discounts and commissions payable solely by X-Energy Reactor Company, LLC in connection with the offer and sale of the securities being registered. All amounts shown are estimated except for the SEC registration fee, the FINRA fee and the stock exchange listing fee.
| | | |
Amount to be paid
|
| |||
|
SEC registration fee
|
| | | $ | * | | |
|
FINRA filing fee
|
| | | $ | * | | |
|
Stock exchange listing fee
|
| | | $ | * | | |
|
Printing expenses
|
| | | $ | * | | |
|
Accounting fees and expenses
|
| | | $ | * | | |
|
Transfer agent and registrar fees
|
| | | $ | * | | |
|
Legal fees and expenses
|
| | | $ | * | | |
|
Total
|
| | | $ | * | | |
*
To be provided by amendment.
Item 14. Indemnification of directors and officers.
Section 102 of the General Corporation Law of the State of Delaware permits a corporation to eliminate the personal liability of directors of a corporation to the corporation or its stockholders for monetary damages for a breach of fiduciary duty as a director, except where the director breached his duty of loyalty, failed to act in good faith, engaged in intentional misconduct or knowingly violated a law, authorized the payment of a dividend or approved a stock repurchase in violation of Delaware corporate law or obtained an improper personal benefit. Our certificate of incorporation provides that no director of X-Energy, Inc. shall be personally liable to it or its stockholders for monetary damages for any breach of fiduciary duty as a director, notwithstanding any provision of law imposing such liability, except to the extent that the General Corporation Law of the State of Delaware prohibits the elimination or limitation of liability of directors for breaches of fiduciary duty.
Section 145 of the General Corporation Law of the State of Delaware provides that a corporation has the power to indemnify a director, officer, employee, or agent of the corporation, or a person serving at the request of the corporation for another corporation, partnership, joint venture, trust or other enterprise in related capacities against expenses (including attorneys’ fees), judgments, fines and amounts paid in settlement actually and reasonably incurred by the person in connection with an action, suit or proceeding to which he was or is a party or is threatened to be made a party to any threatened, ending or completed action, suit or proceeding by reason of such position, if such person acted in good faith and in a manner he reasonably believed to be in or not opposed to the best interests of the corporation, and, in any criminal action or proceeding, had no reasonable cause to believe his conduct was unlawful, except that, in the case of actions brought by or in the right of the corporation, no indemnification shall be made with respect to any claim, issue or matter as to which such person shall have been adjudged to be liable to the corporation unless and only to the extent that the Court of Chancery or other adjudicating court determines that, despite the adjudication of liability but in view of all of the circumstances of the case, such person is fairly and reasonably entitled to indemnity for such expenses which the Court of Chancery or such other court shall deem proper.
Our certificate of incorporation and bylaws provides indemnification for our directors and officers to the fullest extent permitted by the General Corporation Law of the State of Delaware. We will indemnify each person who was or is a party or threatened to be made a party to any threatened, pending or completed action, suit or proceeding (other than an action by or in the right of us) by reason of the fact that he or she is or was,
II-1
or has agreed to become, a director or officer, or is or was serving, or has agreed to serve, at our request as a director, officer, partner, employee or trustee of, or in a similar capacity with, another corporation, partnership, joint venture, trust or other enterprise (all such persons being referred to as an “Indemnitee”), or by reason of any action alleged to have been taken or omitted in such capacity, against all expenses (including attorneys’ fees), judgments, fines and amounts paid in settlement actually and reasonably incurred in connection with such action, suit or proceeding and any appeal therefrom, if such Indemnitee acted in good faith and in a manner he or she reasonably believed to be in, or not opposed to, our best interests, and, with respect to any criminal action or proceeding, he or she had no reasonable cause to believe his or her conduct was unlawful. Our certificate of incorporation and bylaws provides that we will indemnify any Indemnitee who was or is a party to an action or suit by or in the right of us to procure a judgment in our favor by reason of the fact that the Indemnitee is or was, or has agreed to become, a director or officer, or is or was serving, or has agreed to serve, at our request as a director, officer, partner, employee or trustee of, or in a similar capacity with, another corporation, partnership, joint venture, trust or other enterprise, or by reason of any action alleged to have been taken or omitted in such capacity, against all expenses (including attorneys’ fees) and, to the extent permitted by law, amounts paid in settlement actually and reasonably incurred in connection with such action, suit or proceeding, and any appeal therefrom, if the Indemnitee acted in good faith and in a manner he or she reasonably believed to be in, or not opposed to, our best interests, except that no indemnification shall be made with respect to any claim, issue or matter as to which such person shall have been adjudged to be liable to us, unless a court determines that, despite such adjudication but in view of all of the circumstances, he or she is entitled to indemnification of such expenses. Notwithstanding the foregoing, to the extent that any Indemnitee has been successful, on the merits or otherwise, he or she will be indemnified by us against all expenses (including attorneys’ fees) actually and reasonably incurred in connection therewith. Expenses must be advanced to an Indemnitee under certain circumstances.
We maintain a general liability insurance policy that covers certain liabilities of directors and officers of our corporation arising out of claims based on acts or omissions in their capacities as directors or officers.
Item 15. Recent sales of unregistered securities.
C-2 Convertible Notes
In 2022 and 2023, XERC issued convertible notes payable in an aggregate principal amount of $28.0 million and $85.0 million (“C-2 Notes”), respectively, of which $70.0 million of the C-2 Notes were issued to related parties. The C-2 Notes were scheduled to mature on September 30, 2025 and accrue 10.0% of payable-in-kind interest annually.
On October 11, 2024, certain of the C-2 Notes with an aggregate principal balance of $98.0 million converted into 16,960,021 Series C Preferred Units, which was accounted for as a debt extinguishment. As of December 31, 2024, the outstanding principal, inclusive of payable-in-kind interest, on the C-2 Notes was $18.4 million and the fair value was $18.5 million, resulting in a cumulative loss of $0.1 million.
In 2024, the C-2 Notes contained embedded derivatives which, absent the election of the fair value option, would have been bifurcated and accounted for at fair value. Accordingly, the fair value option was elected for the C-2 Notes.
On September 30, 2025, the outstanding principal and unpaid accrued interest on the C-2 Note were converted into 2,870,172 Series C Preferred Units, resulting in the extinguishment of the C-2 Note. Therefore, as of September 30, 2025, there was no outstanding principal on the C-2 Notes.
2024 Convertible Note
On September 26, 2024, the Company entered into a convertible note with Amazon.com NV Investment Holdings LLC in the principal amount of $20.0 million (the “2024 Convertible Note”). While outstanding, the debt accrued paid-in-kind interest of 12% per annum, compounded quarterly. Interest expense recognized related to the 2024 Convertible Note was immaterial through September 30, 2024. On October 11, 2024, in conjunction with the Series C-1 Preferred Units financing discussed below and in accordance with the 2024 Convertible Note’s stated terms, the outstanding principal and interest of the 2024 Convertible Note of $20.1 million was converted into 3,097,477 Series C-1 Preferred Units (“2024 Convertible Note Conversion”).
II-2
2025 Warrant Issuance
On October 3, 2025, XERC issued the 2025 Warrant to a related party to purchase up to 14,123,859 Series C-1 Preferred Units at an exercise price of $6.4870 per unit.
Series D Equity Issuance
On November 21, 2025 and November 25, 2025, XERC issued 48,134,320 and 20,635 Series D Preferred Units, respectively, and received gross cash proceeds of approximately $700.0 million.
December Profits Interest Unit (“PIU”) Issuance
In December 2025, XERC issued 8,230,995 additional Class B-2 PIUs to certain employees.
In connection with the formation transactions described herein and pursuant to the terms of the Reorganization Transactions that will be completed prior to the closing of this offering, we will issue shares of our Class B common stock, representing an aggregate % non-economic interest in us, to the Continuing Equity Owners. Such issuance will not involve any underwriters, underwriting discounts or commissions or a public offering, and such issuance will be exempt from registration requirements pursuant to Section 4(a)(2) of the Securities Act.
Item 16. Exhibits.
(a)
Exhibits
The following documents are filed as exhibits to this registration statement:
|
Exhibit
Number |
| |
Description
|
|
| *1.1 | | | Form of Underwriting Agreement. | |
| 3.1+ | | | Certificate of Incorporation of X-Energy, Inc. | |
| 3.2+ | | | Bylaws of X-Energy, Inc. | |
| *3.3 | | | Form of Amended and Restated Bylaws of X-Energy, Inc. | |
| *5.1 | | | Form of Opinion of Latham & Watkins LLP as to the legality of the securities being registered. | |
| *10.1† | | | Form of X-Energy, Inc. 2026 Incentive Award Plan. | |
| *10.2† | | | Form Restricted Stock Unit Award Agreement under X-Energy, Inc. 2026 Incentive Award Plan | |
| *10.3† | | | Form Option Agreement under X-Energy, Inc. 2026 Incentive Award Plan | |
| *10.4† | | | Offer Letter, dated January 15, 2019, by and between X-Energy, LLC and J. Clay Sell. | |
| *10.5† | | | Offer Letter, dated November 20, 2025, by and between X-Energy, LLC and Daniel Gross. | |
| *10.6† | | |
Offer Letter, dated September 22, 2025, by and between X-Energy Canada, Inc. and Dragan Popovic.
|
|
| *10.7† | | | X-Energy, Inc. Non-Employee Director Compensation Program | |
| *10.8 | | |
Form of Eighth Amended and Restated Limited Liability Company Agreement of X-Energy Reactor Company, LLC.
|
|
| *10.9 | | | Form of Lock-Up Agreement. | |
| *10.10 | | | Form of Master Reorganization Agreement. | |
| *10.11 | | | Form of Shareholder Rights Agreement. | |
| *10.12 | | | Form of Tax Receivable Agreement. | |
| *21.1 | | | List of subsidiaries of X-Energy, Inc. | |
| *23.1 | | |
Consent of Grant Thornton LLP, independent registered public accounting firm to X-Energy Reactor Company, LLC for the fiscal year ended December 31, 2023.
|
|
II-3
|
Exhibit
Number |
| |
Description
|
|
| *23.2 | | |
Consent of Ernst & Young LLP, independent registered public accounting firm to X-Energy Reactor Company, LLC.
|
|
| *23.3 | | |
Consent of Ernst & Young LLP, independent registered public accounting firm to X-Energy, Inc.
|
|
| *23.5 | | | Consent of Latham & Watkins LLP (included as part of Exhibit 5.1 hereto). | |
| *24.1 | | |
Power of Attorney (included on the signature page of the initial filing of this Registration Statement).
|
|
| *99.1 | | | Consent of Director Nominee | |
| *107 | | | Calculation of Filing Fee Table. | |
+
Previously filed.
*
To be filed by amendment.
†
Management contract or compensatory plan or arrangement.
#
Certain schedules and exhibits to this agreement have been omitted pursuant to Item 601(a)(5) of Regulation S-K. A copy of any omitted schedule and/or exhibit will be furnished supplementally to the SEC upon request.
(b) Financial Statement Schedules
See the index to the financial statements included on page F-1 for a list of the financial statements included in this registration statement.
Item 17. Undertakings.
Insofar as indemnification for liabilities arising under the Securities Act may be permitted to directors, officers and controlling persons of the registrant pursuant to the foregoing provisions, or otherwise, the registrant has been advised that in the opinion of the SEC such indemnification is against public policy as expressed in the Securities Act and is, therefore, unenforceable. In the event that a claim for indemnification against such liabilities (other than the payment by the registrant of expenses incurred or paid by a director, officer or controlling person of the registrant in the successful defense of any action, suit or proceeding) is asserted by such director, officer or controlling person in connection with the securities being registered, the registrant will, unless in the opinion of its counsel the matter has been settled by controlling precedent, submit to a court of appropriate jurisdiction the question whether such indemnification by it is against public policy as expressed in the Securities Act and will be governed by the final adjudication of such issue.
The undersigned registrant hereby undertakes that:
(1)
For purposes of determining any liability under the Securities Act, the information omitted from the form of prospectus filed as part of this registration statement in reliance upon Rule 430A and contained in a form of prospectus filed by the registrant pursuant to Rule 424(b)(1) or (4) or 497(h) under the Securities Act shall be deemed to be part of this registration statement as of the time it was declared effective.
(2)
For the purpose of determining any liability under the Securities Act, each post-effective amendment that contains a form of prospectus shall be deemed to be a new registration statement relating to the securities offered therein, and the offering of such securities at that time shall be deemed to be the initial bona fide offering thereof.
II-4
Pursuant to the requirements of the Securities Act of 1933, the registrant has duly caused this registration statement to be signed on its behalf by the undersigned, thereunto duly authorized, in the City of , State of , on , 2026.
X-Energy, Inc.
By:
Name:
J. Clay Sell
Title:
Chief Executive Officer
POWER OF ATTORNEY
Each person whose signature appears below appoints J. Clay Sell and Steven Miller and each of them, any of whom may act without the joinder of the other, as their true and lawful attorneys-in-fact and agents, with full power of substitution and re-substitution, for them and in their name, place and stead, in any and all capacities, to sign any and all amendments (including post-effective amendments) to this registration statement and any registration statement (including any amendment thereto) for this offering that is to be effective upon filing pursuant to Rule 462(b) under the Securities Act of 1933, and to file the same, with all exhibits thereto, and all other documents in connection therewith, with the Securities and Exchange Commission, granting unto said attorneys-in-fact and agents, and each of them, full power and authority to do and perform each and every act and thing requisite and necessary to be done in connection therewith, as fully to all intents and purposes as they might or could do in person, hereby ratifying and confirming all that said attorneys-in-fact and agents, or any of them, or their substitute and substitutes, may lawfully do or cause to be done by virtue hereof.
Pursuant to the requirements of the Securities Act of 1933, this registration statement has been signed by the following persons in the capacities indicated on , 2026.
| |
Signature
|
| |
Title
|
|
| |
J. Clay Sell
|
| |
Chief Executive Officer (Principal Executive Officer)
|
|
| |
Daniel Gross
|
| |
Chief Financial Officer (Principal Financial Officer)
|
|
| |
Kamal Ghaffarian
|
| |
Director
|
|
| |
Edward Sonnenschein
|
| |
Director
|
|
| |
Michael J. Wallace
|
| |
Director
|
|
| |
Kathleen W. Hyle
|
| |
Director
|
|
| |
Christopher F. Ginther
|
| |
Director
|
|
II-5
| |
Signature
|
| |
Title
|
|
| |
David B. Kaplan
|
| |
Director
|
|
| |
Allyson Satin
|
| |
Director
|
|
| |
Gregory Goff
|
| |
Director
|
|
II-6