UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
WASHINGTON, D.C. 20549
FORM 10-K
ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF

THE SECURITIES EXCHANGE ACT OF 1934

FOR THE FISCAL YEAR ENDED JANUARY 31, 2026 COMMISSION FILE NO. 001-09097

REX AMERICAN RESOURCES CORPORATION
(Exact name of registrant as specified in its charter)

Delaware (State or other jurisdiction of incorporation or organization)		31-1095548 (I.R.S. Employer Identification No.)

7720 Paragon Road, Dayton, Ohio (Address of principal executive offices)		45459 (Zip Code)

Registrant’s telephone number, including area code (937) 276-3931

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

Title of each class	Trading Symbol(s)	Name of each exchange on which registered
Common Stock, $.01 par value	REX	New York Stock Exchange

Indicate by check mark if the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act. Yes ☐ No ☑

Indicate by check mark if the registrant is not required to file reports pursuant to Section 13 or Section 15(d) of the Act. Yes ☐ No ☑

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. Yes ☑ No ☐

Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T during the preceding 12 months (or for such shorter period that the registrant was required to submit such files). Yes ☑ No ☐

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

Large accelerated filer ☑ Accelerated filer ☐ Non-accelerated filer ☐ Smaller reporting company ☐ Emerging growth company ☐

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

Indicate by check mark whether the registrant has filed a report on and attestation to its management’s assessment of the effectiveness of its internal control over financial reporting under Section 404(b) of the Sarbanes-Oxley Act (15 U.S.C. 7262(b)) by the registered public accounting firm that prepared or issued its audit report. Yes ☑ No ☐

If securities are registered pursuant to Section 12(b) of the Act, indicated by check mark whether the financial statements of the registrant included in the filing reflect the correction of an error to previous issued financial statements. Yes ☐ No ☑

Indicate by check mark whether any of those error corrections are restatements that required a recovery analysis of incentive-based compensation received by any of the registrant’s executive offices during the relevant recovery period pursuant to §240.10D-1(b). Yes ☐ No ☑

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act) Yes ☐ No ☑

At the close of business on July 31, 2025, the aggregate market value of the registrant’s outstanding Common Stock held by non-affiliates of the registrant (for purposes of this calculation, 2,311,509 shares beneficially owned by directors and executive officers of the registrant were treated as being held by affiliates of the registrant), was $743,279,294.

There were 32,937,718 shares of the registrant’s Common Stock outstanding as of March 27, 2026.

Documents Incorporated by Reference

Portions of REX American Resources Corporation’s definitive Proxy Statement for its Annual Meeting of Shareholders on May 28, 2026 are incorporated by reference into Part III of this Form 10-K.

Commonly Used Defined Terms

*Corporate Structure:*

REX/the Company	REX American Resources Corporation, and its majority and wholly owned subsidiaries
NuGen	NuGen Energy, LLC – REX owns 99.7%
One Earth	One Earth Energy, LLC and subsidiaries – REX owns 76.1%
Big River	Big River, LLC, and subsidiaries – REX owns 10.3%
*Industry Terms:*
CI	Carbon Intensity
CO₂	Carbon dioxide
DDGS	Dried distillers grains
E-10	Gasoline blended with up to 10% ethanol by volume
E-15	Gasoline blended with up to 15% ethanol by volume
E-85	Gasoline blended with up to 85% ethanol by volume
EACs	Energy Attribute Certificates
EISA	Energy Independence and Security Act of 2007
EPA	United States Environmental Protection Agency
FEOC	Foreign Entity of Concern
GHG	Greenhouse Gas
ICC	Illinois Commerce Commission
IRA	Inflation Reduction Act
IRC	Internal Revenue Code of 1986, as amended
IRC Section 45/Section 45	Internal Revenue Code § 45 - Electricity Produced from Certain Renewable Resources, etc.
IRS	Internal Revenue Service
LCFS	Low Carbon Fuel Standard
OBBBA	One Big Beautiful Bill Act
PHMSA	Pipeline and Hazardous Materials Safety Administration
RFA	Renewable Fuels Association
RFS/RFS II	Renewable Fuel Standard/Renewable Fuel Standard II
RIN(s)	Renewable Identification Number(s)
RVOs	Renewable Volume Obligations
Section 45Q/45Q	Section 45Q of the Internal Revenue Code
Section 45Z/45Z	Section 45Z of the Internal Revenue Code
SB	Illinois Senate Bill
SAF	Sustainable Aviation Fuel
SRE(s)	Small Refinery Exemption(s)
USDA	United States Department of Agriculture
USMCA	United States-Mexico-Canada Agreement
*Accounting and General Business Terms:*
ASC	Accounting Standards Codification
ASC 280	ASC 280, “Segment Reporting”
ASC 323	ASC 323, “Investments-Equity Method and Joint Ventures”
ASC 360-05	ASC 360-05, “Impairment or Disposal of Long-lived Assets”
ASC 740	ASC 740, “Income Taxes”
ASC 815	ASC 815, “Derivatives and Hedging”
ASC 820	ASC 820, “Fair Value Measurements and Disclosures”
ASC 842	ASC 842, “Leases”
ASU	Accounting Standards Update
FASB	Financial Accounting Standards Board
RSU	Restricted stock unit
SG&A	Selling, general, and administrative
TSR	Total shareholder return

Forward-Looking Statements

This Form 10-K contains or may contain forward-looking statements as defined in the Private Securities Litigation Reform Act of 1995. Such statements can be identified by use of forward-looking terminology such as “may,” “expect,” “believe,” “estimate,” “anticipate” or “continue” or the negative thereof or other variations thereon or comparable terminology. Readers are cautioned that there are risks and uncertainties that could cause actual events or results to differ materially from those referred to in such forward-looking statements. These risks and uncertainties include the risk factors set forth from time to time in the Company’s filings with the Securities and Exchange Commission and include among other things: the impact of legislative and regulatory changes, the price volatility and availability of corn, distillers grains, ethanol, distillers corn oil, gasoline and natural gas, commodity market risk, ethanol plants operating efficiently and according to forecasts and projections, logistical interruptions, success in permitting and developing the planned carbon sequestration facility near the One Earth Energy ethanol plant, changes in the international, national or regional economies, the impact of inflation, the ability to attract employees, weather, results of income tax audits, changes in income tax laws or regulations such as the OBBBA, the impact of U.S. foreign trade policy and tariffs, changes in foreign currency exchange rates, the effects of terrorism, wars and other conflicts, and the effect of pandemics on the Company’s business operations, including impacts on supplies, demand, personnel and other factors. The Company does not intend to update publicly any forward-looking statements except as required by law. Other factors that could cause actual results to differ materially from those in the forward-looking statements are set forth in Item 1A.

Available Information

REX makes available free of charge on its Internet website its annual report on Form 10-K, quarterly reports on Form 10-Q, current reports on Form 8-K, and amendments to those reports as soon as reasonably practicable after such material is electronically filed with or furnished to the SEC. REX’s Internet website address is www.rexamerican.com. The contents of the Company’s website are not a part of this report.

PART I

Item 1.

Business

References to “we”, “us”, “our”, “REX” or “the Company” refer to REX American Resources Corporation and its majority owned subsidiaries.

Fiscal Year

All references in this report to a particular fiscal year are to REX’s fiscal year ended January 31. We refer to our fiscal year by reference to the calendar year immediately preceding the January 31 fiscal year end date. For example, “fiscal year 2025” means the period February 1, 2025 to January 31, 2026.

Corporate History and Background

REX was incorporated in Delaware in 1984 as a holding company. Our principal offices are located at 7720 Paragon Road, Dayton, Ohio 45459. Our telephone number is (937) 276-3931.

In 2006, we started investing in ethanol production facilities. We are currently invested in three ethanol production entities – One Earth Energy, LLC, NuGen Energy, LLC, and Big River Resources, LLC. We own a majority interest in One Earth and NuGen.

General Overview

We reported net income attributable to REX common shareholders of approximately $83.0 million in fiscal 2025 compared to approximately $58.2 million in fiscal 2024. The current year has benefitted from reductions in our effective tax rate resulting from the impact of 45Z tax credits earned associated with our ethanol production. Gross profit in fiscal year 2025 was higher than fiscal year 2024, primarily a result of higher crush spreads. The two largest drivers of ethanol profitability are corn and ethanol pricing, both of which experienced significant volatility within the year. Chicago Board

of Trade corn prices per bushel ranged from a low of $3.72 in August 2025 to a high of $5.02 in February 2025. S&P Global Platts ethanol pricing per gallon ranged from a low of $1.50 in January 2026 to a high of $2.09 in September 2025.

The form and structure of our ethanol investments are tailored to the specific needs and goals of each project and the local farmer group or investor with whom we partner. We generally participate in the oversight of our projects through our membership on the board of managers of the limited liability companies that own the plants. We provide management oversight and direction with respect to most aspects of plant operations for our consolidated ethanol companies. We have equity investments in three entities engaged in the production of ethanol as of January 31, 2026. The following table is a summary of our ethanol entity ownership interests at January 31, 2026:

Entity	Location	REX’s Current Ownership Interest
One Earth Energy, LLC	Gibson City, IL	76.1%
NuGen Energy, LLC	Marion, SD	99.7%
Big River Resources, LLC: Big River Resources W Burlington, LLC Big River Resources Galva, LLC Big River United Energy, LLC Big River Resources Boyceville, LLC	W. Burlington, IA Galva, IL Dyersville, IA Boyceville, WI	10.3% 10.3% 5.7% 10.3%

The three entities own a total of six ethanol production facilities, which in aggregate shipped approximately 722 million gallons of ethanol over the twelve-month period ended January 31, 2026. REX’s effective ownership of ethanol gallons shipped for the twelve-month period ended January 31, 2026, was approximately 294 million gallons.

Our ethanol operations are highly dependent on commodity prices, especially prices for corn, ethanol, distillers grains, distillers corn oil and natural gas, and availability of corn. As a result of price volatility for these commodities, our operating results can fluctuate substantially. The price and availability of corn is subject to significant fluctuations depending upon several factors that affect commodity prices in general, including crop conditions, the amount of corn stored on farms, weather, federal policy, foreign trade, tariffs and international disruptions caused by wars or conflicts. Because the market prices of ethanol and distillers grains are not always directly related to corn prices (for example, demand for crude and other energy and related prices, the export market demand for ethanol and distillers grains, soybean meal prices, and the results of federal policy decisions, trade negotiations, and tariffs can impact ethanol and distillers grains prices), at times ethanol and distillers grains prices may not follow movements in corn prices and, in an environment of higher corn prices or lower ethanol or distillers grains prices, reduce the overall margin structure at the plants. As a result, at times, we may operate our plants at negative or minimally positive operating margins.

We expect our ethanol plants to produce approximately 2.9 gallons of denatured ethanol for each bushel of corn processed in the production cycle. We refer to the actual gallons of denatured ethanol produced per bushel of corn processed as the realized yield. We refer to the difference between the price per gallon of ethanol and the price per bushel of corn (divided by the realized yield) as the “crush spread.” Should the crush spread decline, it is possible that our ethanol plants will generate operating results that do not provide adequate cash flows for sustained periods of time. In such cases, production at the ethanol plants may be reduced or stopped altogether in order to minimize variable costs at individual plants.

We attempt to manage the risk related to the volatility of commodity prices by utilizing forward corn and natural gas purchase contracts, forward ethanol, distillers grains and distillers corn oil sale contracts, and commodity futures agreements, as management deems appropriate. We attempt to match quantities of these sales contracts with an appropriate quantity of corn purchase contracts over a given period of time when we can obtain an adequate gross margin resulting from the crush spread inherent in the contracts we have executed. However, the market for future ethanol sales contracts generally lags the spot market with respect to ethanol prices. Consequently, we generally execute fixed price ethanol contracts for no more than four months into the future at any given time and we may lock in our corn or ethanol price without having a corresponding locked in ethanol or corn price for short durations of time. As a result of the relatively short period of time our fixed price contracts cover, we generally cannot predict the future movements in our realized crush spread for more than four months; thus, we are unable to predict the likelihood or amounts of future income or loss from the operations of our ethanol facilities.

See “Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations” for details on the Company’s ongoing carbon sequestration and plant expansion projects. These projects are part of the Company’s efforts to maximize the benefits of the federal 45Z tax credits and, subsequent to the expiration of the 45Z tax credits, federal 45Q tax credits, and are subject to ongoing regulatory changes.

We plan to seek and evaluate various investment opportunities including energy related, carbon sequestration, agricultural and other ventures we believe fit our investment criteria. We can make no assurances that we will be successful in our efforts to find such opportunities. We have a stock buyback program with an authorization level of an additional 2,357,186 shares at January 31, 2026 through open market transactions, privately negotiated transactions, or transactions by other means in accordance with applicable securities laws. We typically repurchase our common stock when our stock price is trading at prices we deem to be a discount to the underlying value of our net assets.

Ethanol Industry

Ethanol is a renewable fuel produced by processing corn and other biomass through a fermentation process that creates combustible alcohol that can be used as a fuel additive to reduce vehicle emissions from gasoline, as an octane enhancer to improve the octane rating of gasoline with which it is blended and, to a lesser extent, as a gasoline substitute. The majority of ethanol produced in the United States is made from corn because of its wide availability and ease of convertibility from large amounts of carbohydrates into glucose, the key ingredient in the fermentation process that is used in producing alcohol. Ethanol production can also use feedstocks such as grain sorghum, switchgrass, wheat, barley, potatoes and sugarcane as carbohydrate sources. Most domestic ethanol plants have been located near large corn production areas, such as Illinois, Indiana, Iowa, Minnesota, Nebraska, Ohio and South Dakota. Railway access and interstate access are vital for ethanol facilities due to the large amount of raw materials and finished goods required to be shipped to and from the facilities. An adequate supply of natural gas is key to maintaining optimal operating levels.

According to the RFA, the United States ethanol industry produced an estimated 16.4 billion gallons of ethanol in 2025, compared to 16.1 billion gallons in 2024, and approximately 2.2 billion gallons were estimated to have been exported from the United States in 2025. According to the RFA, the United States ethanol industry consists of 198 plants in 24 states with an annual capacity of approximately 18.5 billion gallons of ethanol production.

Domestic demand for ethanol is highly dependent upon federal and state legislation and regulations. On December 19, 2007, the Energy Independence and Security Act of 2007 (the “Energy Act of 2007”) was enacted. The Energy Act of 2007 established new levels of renewable fuel mandates, including two different categories of renewable fuels: conventional biofuels and advanced biofuels. The federal government mandates the use of renewable fuels under RFS II, established in October 2010. Corn-based ethanol is considered a conventional biofuel. There were mandated volumes established as part of the RFS II for conventional and advanced biofuels through the year 2022. After 2022, RFS volumes are to be determined by the EPA in coordination with the Secretaries of Energy and Agriculture. The mandated volumes for conventional biofuel were to reach 15.0 billion gallons in 2015 and maintain that level until 2022.

The EPA has set conventional renewable fuel volumes of 15.0 billion gallons for 2023 through 2025. Additionally, in 2023, the EPA restored 250 million gallons previously waived. On March 27, 2026, the EPA issued RVOs for 2026 and 2027 of 15.0 billion gallons of conventional ethanol for each year.

The EPA has the authority to waive the biofuel mandate, in whole or in part, if there is inadequate domestic renewable fuel supply or the requirement severely harms the domestic economy or environment. In addition, under RFS II, a small refiner that processes fewer than 75,000 barrels of oil per day can petition the EPA for a waiver of their requirement to submit RINs. The EPA, through consultation with the United States Department of Energy and the USDA, can grant the refiner a full or partial waiver, or deny the waiver. The waiving of a refiner’s obligation effectively lowers the amount of renewable fuels required to be blended, and by extension the amount of RINs that need to be retired, which can impact their values and ultimately blending levels of renewable fuels. There are multiple ongoing legal challenges to how the EPA has handled SREs and RFS rulemaking. On August 22, 2025, the EPA ruled on much of the backlog of SREs, issuing 63 full exemptions, 77 partial exemptions of 50%, 28 denials and 7 ruled as ineligible. On November 7, 2025, the EPA issued two 100% waivers, twelve 50% waivers and two denials. As of March 19, 2026, there were 37 SRE petitions pending from compliance years 2023-2025.

Ethanol Production

The plants in which we have invested are designed to use the dry milling method of producing ethanol. In the dry milling process, the entire corn kernel is first ground into flour, which is referred to as “meal,” and processed without separating out the various component parts of the grain. The meal is processed with enzymes, chemicals and water, and then placed in a high-temperature cooker. It is then transferred to fermenters where yeast is added and the conversion of sugar to ethanol begins. After fermentation, the resulting liquid is transferred to distillation columns where the ethanol is separated from the remaining “stillage” for fuel uses. The anhydrous ethanol is then blended with a denaturant, such as natural gasoline, to render it undrinkable and thus not subject to beverage alcohol tax. With the starch elements of the corn consumed in the above-described process, the principal by-product produced by the dry milling process is dry distillers grains with solubles, or DDGS. DDGS is sold as a protein used in animal feed, which utilizes a portion of the corn value not absorbed in ethanol production. Depending on market and operating conditions, we may also sell modified distillers grains, or wet distillers grains, by removing less liquid content compared to DDGS. We also generate revenues from the sale of distillers corn oil produced at our facilities. Distillers corn oil is sold to the animal feed market, as well as biodiesel and other chemical markets.

The Primary Uses of Ethanol

Blend component. Today, much of the ethanol blending in the U.S. is done to meet the RFS. Most regular gasoline is produced using blendstock with an octane rating of 84, which is then increased to 87 (the minimum octane rating required in most states) by adding 10% ethanol according to the RFA. The industry is attempting to expand ethanol blending above the current 10% for most vehicles in use. The EPA has approved the use of E-15, which has an octane rating of 88, in gasoline for cars, SUV’s and light duty trucks made in 2001 and later. Previously, the EPA had not granted E-15 the same Reid vapor pressure waiver as E-10 so it could only be sold from September 16 through May 31 for those vehicles in most markets. The EPA issued emergency waivers to allow the sale of E-15 for the summer months in the years 2022 through 2026. Eight Midwest states (Illinois, Iowa, Minnesota, Missouri, Nebraska, Ohio, South Dakota, and Wisconsin) petitioned the EPA to allow year-round sales of E-15 in their states. The EPA approved this request beginning in 2025 but will consider requests from individual states to delay implementation by one year. Ohio and South Dakota previously requested a one-year delay, which the EPA has approved. Ohio has since opted out of the agreement.

Clean air additive. Ethanol is employed by the refining industry as a fuel oxygenate, which when blended with gasoline, allows engines to combust fuel more completely than gasoline that has not been oxygenated and thus reduce emissions from motor vehicles. Ethanol contains 35% oxygen, which results in more complete combustion of the fuel in the engine cylinder. Oxygenated gasoline is used to help meet certain federal and air emission standards.

Octane enhancer. Ethanol increases the octane rating of gasoline with which it is blended. Octane is a measure of fuel performance. Ethanol is used by gasoline suppliers as an octane enhancer both for producing regular grade gasoline from lower octane blending stocks and for upgrading regular gasoline to premium grades.

Legislation

The United States ethanol industry is highly dependent upon federal and state legislation. See Item 1A. Risk Factors for a discussion of legislation affecting the U.S. ethanol industry.

Refined Coal Facility

On August 10, 2017, we purchased, through a 95.35% owned subsidiary, the entire ownership interest of an entity that owned a refined coal facility. We began operating the refined coal facility immediately after the acquisition. Using licensed technology, our plant applied two separate chemicals to convert feedstock coal into refined coal, which was sold to the end user of the refined coal. The refined coal operating results were subsidized by federal production tax credits through November 18, 2021, subject to meeting qualified emissions reductions as governed by Section 45 of the IRC. We ceased operating the facility on November 18, 2021 and subsequently sold the facility. The federal production tax credits received through ownership of this facility, approximately $58.2 million, remain under IRS audit. That audit is in the process of being finalized, with the Company expecting to retain all federal production tax credits claimed.

Facilities

As of our fiscal year end, our consolidated ethanol entities owned a combined 1,591 acres of land and two facilities that shipped a combined quantity of approximately 294 million gallons of ethanol in fiscal year 2025. We also own our corporate headquarters office building, consisting of approximately 7,500 square feet, located in Dayton, Ohio.

Human Capital Resources

The attraction, retention and development of employees is critical to our success. We accomplish these objectives through a variety of actions, including our competitive compensation policies, discretionary stock award programs, training initiatives, and growth opportunities within our Company. At January 31, 2026, we had 132 employees at our two consolidated ethanol plants and at our corporate headquarters. None of our employees are represented by a labor union. We expect this employment level to remain relatively stable, subject to changes upon startup of the carbon sequestration facility. We consider our relationship with our employees to be good.

We conduct regularly scheduled safety meetings and require all employees to go through safety training. We evaluate employee safety incidents monthly and investigate such incidents promptly. In addition, we conduct periodic safety audits performed by an independent third party. A portion of our incentive compensation plan rewards employees for attaining certain safety goals.

We believe we offer market competitive compensation and benefit programs for our employees. In addition to competitive base wages, all employees are eligible for an incentive compensation program, a Company matched 401(k) plan, healthcare benefits, and paid time off.

Service Marks

We have registered the service marks “REX” and “Farmer’s Energy” with the United States Patent and Trademark Office. We are not aware of any adverse claims concerning our service marks.

Item 1A.

Risk Factors

We encourage you to carefully consider the risks described below and other information contained in this report when considering an investment decision in REX common stock. Any of the events discussed in the risk factors below may occur. If one or more of these events do occur, our results of operations, financial condition or cash flows could be materially adversely affected. In this instance, the trading price of REX stock could decline, and investors might lose all or part of their investment.

Risks Related to our Ethanol and By-Products Business

The financial returns on our ethanol investments are highly dependent on commodity prices, which are subject to significant volatility, uncertainty and regional supply shortages, so our results could fluctuate substantially.

The financial returns on our ethanol investments are highly dependent on commodity prices, especially prices for corn, natural gas, ethanol, distillers grains, distillers corn oil and gasoline, and availability of corn. As a result of the volatility of the prices for these items, our returns may fluctuate substantially and our investments could experience periods of declining prices for their products and increasing costs for their raw materials, which could result in operating losses at our ethanol plants.

The gross margin at our ethanol plants depends principally on the spread between ethanol, distillers grains, distillers corn oil, and corn prices. Fluctuations in the spread are likely to continue to occur. A sustained narrow or negative spread, whether as a result of sustained high or increased corn prices or sustained low or decreased ethanol prices, would adversely affect the results of operations at our ethanol plants.

Our returns on ethanol investments are highly sensitive to corn prices.

Corn is the principal raw material our ethanol plants use to produce ethanol and by-products. As a result, changes in the price of corn can significantly affect our businesses. Rising corn prices result in higher production costs of ethanol and by-products. Because ethanol competes with non-corn-based fuels, our ethanol plants may not be able to pass along increased grain costs to our customers. At certain levels, grain prices may make ethanol uneconomical to produce.

The price of corn is influenced by weather conditions and other factors affecting crop yields, transportation costs, farmer planting decisions including input costs, exports, foreign production, the value of the U.S. dollar, and general domestic and foreign economic, market and regulatory factors, including, but not limited to, the impacts from the Russian-Ukraine and Middle Eastern conflicts as well as other conflicts and political unrest, both foreign and domestic. These factors include government policies and subsidies with respect to agriculture, international trade and tariffs, and global and local demand and supply. The significance and relative effect of these factors on the price of corn is difficult to predict. Any event that tends to negatively affect the production and/or supply of corn, such as adverse weather or crop disease, could increase corn prices and potentially harm the business of our ethanol plants, to include intermittent production slowdowns or stoppages. Increasing domestic ethanol production could boost the demand for corn and result in increased corn prices. International demand for corn could also result in higher or lower corn prices. Our ethanol plants may also have difficulty, from time to time, in physically sourcing corn on economic terms due to regional supply shortages, transportation issues, delays in farmer marketing decisions or unfavorable local pricing. Such a shortage or price impact could require our ethanol plants to suspend operations which would have a material adverse effect on our consolidated results of operations.

Our risk management strategies may be ineffective and may expose us to decreased profitability and liquidity.

In an attempt to partially offset the impact of volatility of commodity prices, we enter into: i) forward contracts to sell a portion of our ethanol, distillers grains, and distillers corn oil production and to purchase a portion of our corn and natural gas requirements and; ii) commodity futures and swap agreements. The financial impact of these risk management activities is dependent upon, among other items, the prices involved and our ability to receive or deliver the commodities involved. Risk management activities can result in financial loss when positions are purchased in a declining market or when positions are sold in an increasing market. In addition, we may not be able to match the appropriate quantity of corn contracts with quantities of ethanol, distillers grains and distillers corn oil contracts. Further, our results may be impacted by a mismatch of gains or losses associated with the positions during a reporting period when the physical commodity purchase or sale has not yet occurred. We vary the amount and type of risk management techniques we utilize, and we may choose not to engage in any risk management activities. Should we fail to properly manage the inherent volatility of commodity prices, our results of operations and financial condition may be adversely affected.

The market for natural gas is subject to market conditions that create uncertainty in the price and availability of the natural gas that our ethanol plants use in their manufacturing process.

Our ethanol plants rely upon third parties for their supply of natural gas, which is consumed as fuel in the production process. The prices for and availability of natural gas are subject to volatile market conditions. These market conditions often are affected by factors beyond the ethanol plants’ control, such as weather conditions, overall economic conditions, export market, governmental regulation and foreign and domestic relations, including, but not limited to, the impacts from the Russian-Ukraine and Middle Eastern conflicts. Significant disruptions in the supply of natural gas could impair or completely prevent the ethanol plants’ ability to economically manufacture ethanol for their customers. Furthermore, increases in natural gas prices may adversely affect results of operations and financial position at our ethanol plants.

Fluctuations in the selling price of commodities may reduce profit margins at our ethanol plants.

Ethanol is marketed as a fuel additive to reduce vehicle emissions from gasoline, as an octane enhancer to improve the octane rating of gasoline with which it is blended and, to a lesser extent, as a gasoline substitute. As a result, ethanol prices are influenced by the supply and demand for gasoline, and our ethanol plants’ results of operations and financial position may be materially adversely affected if gasoline demand decreases or the price of gasoline declines making ethanol less economical.

Distillers grains compete with other protein-based animal feed products. The price of distillers grains may decrease when the prices of competing feed products decrease. The prices of competing animal feed products are based in part on the prices of the commodities from which these products are made. Historically, sales prices for distillers grains have tracked along with the price of corn and soybean meal. However, there have been instances when price increases for distillers grains have lagged increases in corn prices.

The production of distillers grains has increased as a result of increases in dry mill ethanol production in the United States. This could lead to price declines in what we can sell our distillers grains for in the future. Such declines could have a material adverse effect on our results of operations.

Pricing of distillers corn oil is primarily driven by the demand from renewable diesel, biodiesel, and to some extent, synthetic aviation fuel markets. Distillers corn oil is marketed as a low-carbon feedstock to be used in these markets which may see expanded demand due to the extended blending tax credit, credits included in the IRA and LCFS markets, resulting in an impact to distillers corn oil demand. With a lower CI score, distillers corn oil may see improved pricing compared to heating oil and soybean oil, which it has traditionally tracked closely in price. Alternatively, other feedstocks such as cooking oil and animal fats, with lower CI scoring, could be preferred over distillers corn oil. A decrease in the price of or demand for distillers corn oil could negatively impact our results of operations.

Inflation could impact the cost and/or availability of material, labor and other input, which could adversely affect our operations.

We have experienced inflationary impacts on key production inputs, labor costs consisting of both wages and other labor-related costs, services, equipment and other inputs. These inflationary pressures could continue or worsen in future periods and may be beyond our control. We may not be able to pass these increased costs along to our customers through the products we sell. As a result, inflation and higher prices could negatively impact our results of operations.

We are currently working on carbon sequestration and plant expansion projects at the One Earth plant. We have experienced permitting delays which could lead to inflationary pricing increases on the construction.

The price of ethanol and distillers grains may decline as a result of trade restrictions, duties or tariffs on ethanol and distillers grains exports from the United States or from unfavorable foreign currency exchange rates.

Ethanol and other products that we produce are sold into various other countries with trade agreements with the United States. If the United States were to withdraw from or materially modify certain international trade agreements, our business, financial condition and results of operations could be materially adversely affected. In addition, there have been increased threats of tariffs on imports by the current Trump administration. If tariffs lead to retaliatory actions by countries that are markets for our products, it could have material adverse effect on our business, financial condition and results of operations.

The United States exported an estimated 2.2 billion gallons of ethanol in 2025, up from approximately 1.9 and 1.4 billion gallons in 2024 and 2023, respectively. 36% of the 2025 exports of ethanol were sold in Canada. Further, in 2025 and 2024, an estimated 11.6 and 12.1 million metric tons, respectively, of distillers grains were exported by the United States, which represented approximately 36% and 37% in 2025 and 2024, respectively, of U.S production. Of the total United States exports of distillers grains in 2025, 20% were exported to Mexico. If producers and exporters of ethanol and distillers grains are subjected to trade restrictions, or additional duties or tariffs are imposed on U.S. exports, particularly by Canada and Mexico, it may make it uneconomical to export these products. The industry has experienced various trade policy disputes, tariffs and investigations in foreign countries that have adversely impacted the international demand for our products. Reduced international demand could lead to further oversupply and reduce pricing.

Increased ethanol production or decreases in demand for ethanol may result in excess production capacity in the ethanol industry, which may cause the price of ethanol, distillers grains and distillers corn oil to decrease.

According to the RFA, domestic ethanol production capacity is approximately 18.5 billion gallons per year. Under RFS II, there were mandated volumes through 2022 for conventional and advanced biofuels. After 2022, RFS volumes are to be determined by the EPA in coordination with the Secretaries of Energy and Agriculture. The EPA has set conventional

renewable fuel volumes of 15.0 billion gallons for 2023 through 2025. In addition, for 2023 the EPA restored 250 million gallons previously waived. On March 27, 2026, the EPA issued RVOs for 2026 and 2027 of 15.0 billion gallons of conventional ethanol for each year. The excess capacity over the EPA proposed volumes could have an adverse effect on the results of our operations. In a manufacturing industry with excess capacity, producers have an incentive to manufacture additional products for so long as the price exceeds the marginal cost of production (i.e., the cost of producing only the next unit, without regard for interest, overhead or fixed costs). This incentive could result in the reduction of the market price of ethanol to a level that is inadequate to generate sufficient cash flow to cover costs.

A decrease in demand for ethanol may also result in excess capacity, which could result from a number of factors, including, but not limited to, regulatory developments, reduced U.S. gasoline consumption, and increases in gasoline prices. Reduced gasoline consumption could occur as a result of increased prices for gasoline or crude oil, which could cause businesses and consumers to reduce driving or acquire vehicles with more favorable gasoline mileage or acquire non-gasoline powered vehicles. In addition, decreased overall economic activity could also lead to reduced gasoline consumption.

In addition, because ethanol production produces distillers grains and distillers corn oil as by-products, increased ethanol production will also lead to increased supplies of distillers grains and distillers corn oil. An increase in the supply of distillers grains and distillers corn oil, without corresponding increases in demand, could lead to lower prices or an inability to sell our ethanol plants’ distillers grains and distillers corn oil production. A decline in the price of distillers grains or distillers corn oil could have a material adverse effect on the results of our business, financial condition, and results of operations.

Future demand for ethanol is uncertain and changes in overall consumer demand for transportation fuel could affect demand.

There are limited markets for ethanol other than what is federally mandated. Increased consumer acceptance of E-15 and E-85 fuel is likely necessary in order for ethanol to achieve significant market share growth beyond federal mandate levels.

Consumer demand for gasoline may be impacted by emerging transportation trends, such as hybrid and electric vehicles. Some automobile manufacturers have announced plans to phase out internal combustion engine production by the mid-2030s. There also have been pledges to ban the sale of internal combustion engines in countries such as Japan and the United Kingdom by 2035, as well as a statewide ban in California, which several states are imitating. If realized, these bans would accelerate the decline of liquid fuel demand and by extension demand for ethanol, biodiesel and renewable diesel. Recent federal legislation seeks to address the ever-increasing demand for electric vehicle infrastructure. Reduced demand for ethanol could cause our results of operations to be materially impacted.

We may not successfully develop our planned carbon sequestration facility near the One Earth Energy ethanol plant.

The Company has committed significant time and resources towards a carbon sequestration project near the One Earth Energy ethanol plant. The completion and start-up of this project requires numerous government approvals. If we are not successful in obtaining all these approvals, we may not be able to complete this project and could result in a significant write off of our commitments and investment, which totals approximately $58.9 million as of our most recent year-end. Recent delays in permitting could result in increased costs to complete the project.

If we are not successful on this project, our ethanol plant could be at a disadvantage in the industry as our inability to sequester our carbon could result in a higher CI score than our competitors if they are able to sequester their carbon. If we are unable to reduce our CI score, we may not be able to participate in the state and federal clean fuel programs, including federal tax credits outlined in the IRA and OBBBA.

Carbon capture and sequestration projects are subject to federal, state, and local regulations.

In addition to our planned carbon sequestration facility near our One Earth Energy ethanol plant, we have signed an agreement to deliver our carbon from the NuGen Energy facility to an outside party. These projects may not result in any realized benefit due to delays or suspended operations. Investments being made in these projects are based on regulatory guidelines, such as modeling for CI reductions, that may be adjusted outside of our control and could deviate from our current strategy. Delays in the issuance or regulations or the elimination of clean fuel and other incentives at the federal, state or local level could adversely affect our business. New legislation limiting our ability to sequester carbon could be adopted at the federal, state or local levels.

We have secured land easements from all necessary landowners to allow the construction of the CO₂ connector pipeline on their land from the ethanol plant to the first two injection wells for our carbon sequestration project near the One Earth Energy ethanol facility. We also have landowner subsurface easements for the first injection well with capacity sufficient to allow for carbon sequestration for our One Earth plant for an estimated 15 years. In July 2024, the governor of Illinois signed the Safety and Aid for the Environment in Carbon Capture and Sequestration Act. This legislation imposes additional safety, environmental and other requirements on obtaining permits and approvals for carbon capture and sequestration facilities in Illinois, including CO₂ pipelines. Further, the legislation imposes a moratorium on the issuance of new certificates of authority for the construction of CO₂ pipelines until the earlier of the date federal CO₂ pipeline safety standards are finalized by the federal PHMSA or, subject to certain other conditions, July 1, 2026. As a result of this legislation, the ICC dismissed our pipeline application without prejudice, and we will be required to resubmit an application after rules are finalized or subsequent to July 1, 2026. The delays and additional requirements imposed as a result of this act could have an adverse impact on the cost and completion of our project.

In March 2025, South Dakota enacted a law that bans the use of eminent domain in connection with carbon dioxide pipelines. In addition, in March 2026, a North Dakota Court voided the permits issued to Summit Carbon Solutions for underground storage of carbon dioxide as the Court has deemed the law the permits were issued under to be unconstitutional. Our NuGen ethanol plant has a contract to be a part of this project. Summit Carbon Solutions is analyzing the decision and is contemplating next steps. These actions could make the sequestration project for the NuGen facility more difficult for Summit Carbon Solutions to complete.

Our ability to generate 45Z production tax credits involves regulatory and market uncertainties.

We expect our consolidated ethanol plants will be able to claim 45Z tax credits for 2025 based on current laws and proposed regulations. Guidelines issued by the U.S. Department of Treasury are still being finalized. Costs associated with 45Z compliance, including prevailing wage and apprenticeship requirements, could become material. Changes in these requirements, as well as changes in CI score modeling, could have a material impact on the amount of credits we are able to claim.

45Z tax credits can be utilized by the taxpayer to reduce income tax payments or the credits can be monetized externally. Fluctuations in demand, uncertainty within the tax credit market and changes in regulations can all impact our ability to monetize the credits, or impact the value at which the credits can be monetized.

We depend on our partners to operate certain of our ethanol investments.

Our investments currently represent both majority and minority equity positions. Day-to-day operating control of minority owned plants generally remains with the local investor group. We do not have the ability to directly modify the operations of these plants in response to changes in the business environment or in response to any deficiencies in local operations of the plants. In addition, local plant operators, who also represent the primary suppliers of corn and other crops to the plants, may have interests, such as the price and sourcing of corn and other crops, that may differ from our interest, which is based solely on the operating profit of the plant. The limitations on our ability to control day-to-day plant operations could adversely affect plant results of operations.

We may not successfully acquire or develop additional ethanol investments or expansion.

The growth of our ethanol business depends on our ability to identify and develop new ethanol investments. Any expansion strategy will depend on prevailing market conditions for the price of ethanol and the cost of corn and natural gas and the expectations of future market conditions. Additional financing may also be necessary to implement any expansion strategy, which may not be accessible or available on acceptable terms. In addition, failure to adequately manage the risks associated with additional ethanol investments could have a material adverse effect on our business.

Our ethanol plants may be adversely affected by technological advances and efforts to anticipate and employ such technological advances may prove unsuccessful.

The development and implementation of new technologies may result in a significant reduction in the costs of ethanol production. For instance, any technological advances in the efficiency or cost to produce ethanol from inexpensive cellulosic sources such as corn stalk, wheat, oat or barley straw could have an adverse effect on our ethanol plants, because our plants are designed to produce ethanol from corn, which is, by comparison, a raw material with other high value uses. We cannot predict when, or if, new technologies may become available, the rate of acceptance of new technologies by competitors or the costs associated with new technologies. In addition, advances in the development of alternatives to ethanol could significantly reduce demand for or eliminate the need for ethanol.

Any advances in technology which require significant unanticipated capital expenditures to remain competitive or which reduce demand or prices for ethanol would have a material adverse effect on the results of our ethanol operations.

In addition, alternative fuels, additives and oxygenates are continually under development. Alternative fuel additives that can replace ethanol may be developed, which may decrease the demand for ethanol. It is also possible that technological advances in engine and exhaust system design and performance could reduce the use of oxygenates, which would lower the demand for ethanol. Reduced demand for ethanol could cause our results of operations to be materially adversely affected.

The U.S. ethanol industry is highly dependent upon a myriad of federal and state legislation and regulation and any changes in legislation or regulation could materially and adversely affect our results of operations and financial position.

The renewable fuel standard program was authorized under the Energy Policy Act of 2005 and was expanded under the EISA. EISA increased the amount of renewable fuel required to be blended into gasoline with RFS II and required a minimum usage of corn-derived renewable fuels of 12.0 billion gallons in 2010, increasing annually by 600 million gallons to 15.0 billion gallons in 2015 through 2022, with no specified volume subsequent to 2022. After 2022, RFS volumes are to be determined by the EPA in coordination with the Secretaries of Energy and Agriculture. The EPA has the authority to assign the mandated amounts of renewable fuels to be blended into transportation fuel to individual fuel blenders. RFS II has been a primary factor in the growth of ethanol usage. Over the past several years various pieces of legislation have been introduced to the U.S. Congress that were intended to reduce or eliminate ethanol blending requirements. To date, none of the bills have been successful but they are an indication of the continued effort to undermine the EISA.

The EPA has set conventional renewable fuel volumes of 15.0 billion gallons for 2023 through 2025. Additionally, for 2023, the EPA restored 250 million gallons previously waived. On March 27, 2026, the EPA issued RVOs for 2026 and 2027 of 15.0 billion gallons of conventional ethanol for each year.

Obligated parties use RINs to show compliance with RFS-mandated volumes. RINs are attached to renewable fuels by producers and detached when the renewable fuel is blended with transportation fuel or traded in the open market. The market price of detached RINs affects the price of ethanol in certain markets and influences the purchasing decisions by obligated parties. As a result of fluctuations in RINs pricing, certain obligated parties have petitioned the EPA and filed court actions to change the point of obligation or to seek relief from their obligation. The EPA has the authority to waive the biofuel mandate, in whole or in part, if there is inadequate domestic renewable fuel supply or the requirement severely

harms the domestic economy or environment. In addition, under RFS II, a small refiner that processes fewer than 75,000 barrels of oil per day can petition the EPA for a waiver of their requirement to submit RINs. The EPA, through consultation with the United States Department of Energy and the USDA, can grant the refiner a full or partial waiver, or deny the waiver. The waiving of a refiner’s obligation effectively lowers the amount of renewable fuels required to be blended, and by extension the amount of RINs that need to be retired, which can impact their values and ultimately blending levels of renewable fuels. There are multiple ongoing legal challenges to how the EPA has handled SREs and RFS rulemaking. On August 22, 2025, the EPA ruled on much of the backlog of SREs, issuing 63 full exemptions, 77 partial exemptions of 50%, 28 denials and 7 ruled as ineligible. On November 7, 2025, the EPA issued two 100% waivers, twelve 50% waivers and two denials. As of March 19, 2026, there were 37 SRE petitions pending from compliance years 2023-2025.

Flexible fuel vehicles (“FFVs”) receive preferential treatment in meeting federally mandated corporate average fuel economy (“CAFE”) standards for automobiles manufactured by car makers. High blend ethanol fuels such as E-85 result in lower fuel efficiencies. Absent the CAFE preferences, car makers would not likely build flexible-fuel vehicles. In recent years, automobile manufactures have lowered the production of FFVs for the U.S. Any change in CAFE preferences could reduce the growth of E-85 markets and result in lower ethanol prices.

Unfavorable changes in legislation or regulations could materially and adversely affect our results of operations and financial position.

The inability to generate or obtain RINs could adversely affect our operating results.

Virtually all our ethanol is sold with RINs that are used by customers to comply with RFS II. If our production does not meet EPA requirements for RIN generation, as an efficient producer, in the future, we would have to purchase RINs in the open market or sell our ethanol at substantially lower prices, such as on the export market, to adjust for the absence of RINs. The price of RINs varies based on many factors and cannot be predicted. Failure to obtain sufficient RINs or reliance on invalid RINs could subject us to fines and penalties imposed by the EPA.

Various studies have criticized the efficiency of ethanol, in general, and corn-based ethanol in particular, which could lead to the reduction or repeal of incentives and tariffs that promote the use and domestic production of ethanol or otherwise negatively impact public perception and acceptance of ethanol as an alternative fuel.

Although many trade groups, academics and governmental agencies have supported ethanol as a fuel additive that promotes a cleaner environment, others have criticized ethanol production as consuming considerably more energy and emitting more greenhouse gases than other biofuels and as potentially depleting water resources. Other studies have suggested that corn-based ethanol negatively impacts consumers by causing prices to increase for dairy, meat and other foodstuffs.

If these views gain acceptance, support for existing measures promoting use and domestic production of corn-based ethanol could decline, leading to reduction or repeal of these measures. These views could also negatively impact public perception of the ethanol industry and acceptance of ethanol as an alternative fuel.

Federal support of cellulosic ethanol may result in reduced incentives to corn-derived ethanol producers.

The American Recovery and Reinvestment Act of 2009 and EISA provide funding opportunities in support of cellulosic ethanol obtained from biomass sources such as switchgrass and poplar trees. These federal policies may suggest a long-term political preference for cellulosic processes using alternative feedstocks such as switchgrass, silage or wood chips. Cellulosic ethanol has a smaller carbon footprint than corn-derived ethanol and is unlikely to divert foodstuff from the market. Our plants are designed as single-feedstock facilities, located in corn production areas with limited alternative feedstock nearby, and would require significant additional investment to convert to the production of cellulosic ethanol. The adoption of cellulosic ethanol as the preferred form of ethanol could have a significant adverse effect on our ethanol business.

Our ethanol business is affected by environmental and other regulations which could impede or prohibit our ability to successfully operate our plants.

Our ethanol production facilities are subject to extensive air, water discharge, and other environmental regulations. We have had to obtain numerous permits to construct and operate our plants. Regulatory agencies could impose conditions or other restrictions in the permits that are detrimental, or which increase our costs. More stringent federal or state environmental regulations could be adopted which could significantly increase our operating costs or require us to expend considerable resources.

Our ethanol plants emit various airborne pollutants as by-products of the ethanol production process, including carbon dioxide (a greenhouse gas). In 2007, the U.S. Supreme Court classified carbon dioxide as an air pollutant under the Clean Air Act in a case seeking to require the EPA to regulate carbon dioxide in vehicle emissions. In February 2010, the EPA released its final regulations on the Renewable Fuel Standard program. We believe our plants are grandfathered up to certain operating capacity, but plant expansion requires us to meet a 20% threshold reduction in GHG emissions from a 2005 baseline measurement to produce ethanol eligible for the RFS II mandate. To further expand our plant capacity, we may be required to obtain additional permits, install advanced technology equipment, or reduce drying of certain amounts of distillers grains. We may also be required to install carbon dioxide mitigation equipment or take other steps in order to comply with future laws or regulations. Compliance with future laws or regulations with respect to emissions of carbon dioxide, or if we choose to expand capacity at certain of our plants, compliance with then-current regulations of carbon dioxide, could be costly and may prevent us from operating our plants at full capacity or as profitably, which may have a negative impact on our financial performance. We also face the risk of ethanol production above our grandfathered capacity not qualifying for RINs if the plants do not meet certain emission requirements.

The California Air Resources Board adopted a LCFS requiring a 10% reduction in GHG emissions from transportation fuels. An Indirect Land Use Charge is included in this lifecycle GHG emission calculation. This standard could have an adverse impact on the market for corn-based ethanol in California if corn-based ethanol fails to achieve lifecycle GHG emission reductions and in other states if they adopt similar standards. This could have a negative impact on our financial performance.

Our ethanol business may become subject to various environmental and health and safety and property damage claims and liabilities.

Operation of our ethanol business exposes the business to the risk of environmental and health and safety claims and property damage claims, such as failure to comply with environmental regulations. These types of claims could also be made against our ethanol business based upon the acts or omissions of other persons. Serious claims could have a material negative impact on our results of operations, financial position and future cash flows.

Our business is not diversified.

Our financial results depend heavily on our ability to operate our ethanol plants profitably. Our lack of diversification could have a material negative impact on our results of operations, financial position and future cash flows should our ethanol plants operate unprofitably.

We may not be able to meet commitments to produce and sell ethanol.

We may, at times, sell our products with forward contracts. If we are unable to produce the products due to economic conditions, business interruption, or other factors, we may incur additional costs or have to obtain commodities at unfavorable prices to meet our contractual commitments. This could have a material adverse effect on our results of operations.

We may not be able to meet commitments to purchase commodities.

We may, at times, purchase certain commodities with forward contracts without a corresponding quantity of ethanol sold via forward contracts at known prices. Should ethanol and by-product prices decline to levels that would lead to significant unprofitable results of operations, we may incur additional costs and/or losses to meet our contractual commitments. This could have a material adverse effect on our results of operations.

Our revenue from the sale of distillers grains depends upon its continued market acceptance as an animal feed.

Distillers grains is a by-product from the fermentation of corn to produce ethanol. Antibiotics may be used during the fermentation process to control bacterial contamination; therefore, antibiotics may be present in small quantities in distillers grains marketed as animal feed. The U. S. Food and Drug Administration’s Center for Veterinary Medicine has expressed concern about potential animal and human health hazards from the use of distillers grains as an animal feed due to the possibility of antibiotic residues. If the public became concerned about the impact of distillers grains in the food supply or as an acceptable animal feed, the market for distillers grains could be negatively impacted, which would have a negative impact on our results of operations. We may not be able to obtain a suitable replacement for antibiotics, should this be required, which would also negatively impact the market for distillers grains.

An estimated 36% of distillers grains produced in the United States were exported in 2025. The price of distillers grains has benefitted from the exports of the product. In recent years, certain countries have refused to import U.S. distillers grains for a variety of reasons. If export shipments are rejected or delayed, the market price for distillers grains would be negatively impacted, which would have a negative impact on our ethanol results of operations.

We extract distillers corn oil immediately prior to the production of distillers grains. Several studies are attempting to determine whether distillers corn oil extraction may impact the nutritional value of the resulting distillers grains. If it is determined that distillers corn oil extraction adversely impacts the nutritional energy content of distillers grains, the value of the distillers grains we sell may be negatively impacted, which would have a negative impact on our results of operations.

We face significant competition in the ethanol industry.

We face significant competition for new ethanol investment opportunities. Many of our competitors are larger and may have greater financial resources than we do. We must compete for investment opportunities based on our strategy of supporting and enhancing local development of ethanol plant opportunities. We may not be successful in competing for investment opportunities based on our strategy.

The ethanol industry is primarily comprised of entities that engage exclusively in ethanol production and large integrated grain companies that produce ethanol along with their base grain business. Several large oil companies have entered the ethanol production market. If these companies increase their ethanol plant ownership or if other oil companies seek to engage in direct ethanol production, there would be less of a need to purchase ethanol from independent producers such as our ethanol plants. No assurance can be given that our ethanol plants will be able to compete successfully or that competition from larger companies with greater financial resources will not have a materially adverse impact on the results of our ethanol operations.

We may face competition from foreign producers.

There is a risk of foreign competition in the ethanol industry. Brazil is presently the second largest producer of ethanol in the world. Brazil’s ethanol production is mostly sugarcane based, and, depending on feedstock prices, may be cheaper to produce than corn-derived ethanol. Under the RFS, certain parties were obligated to meet an advanced biofuel standard. In recent years, sugarcane-based ethanol imported from Brazil has been one of the most economical means for obligated parties to comply with this standard.

If significant additional foreign ethanol production capacity is created, such facilities could create excess supplies of ethanol, which may result in lower prices of ethanol. In addition, foreign ethanol producers may be able to produce ethanol at costs lower than ours. These risks could have significant adverse effects on our financial performance.

We are exposed to credit risk from our sales of ethanol and distillers grains to customers.

The inability of a customer to make payments to us for our accounts receivable may cause us to experience losses and may adversely impact our liquidity and our ability to make our payments when due.

We may not be able to hire and retain qualified personnel to operate our ethanol plants and carbon sequestration facility.

Our ability to attract and retain competent personnel has a significant impact on operating efficiencies and plant profitability. Competition for key plant employees in the ethanol industry can be intense, and there has been an increased demand for workers in the U.S. We may not be able to attract and retain qualified employees. Failure to do so could have a negative impact on our financial results at individual plants.

Our plants depend on an uninterrupted supply of energy and water to operate. Unforeseen plant shutdowns could harm our business.

Our plants require a significant and uninterrupted supply of natural gas, electricity and water to operate. We generally rely on third parties to provide these resources. If there is an interruption in the supply of energy or water for any reason, such as supply, delivery or mechanical problems and we are unable to secure an adequate alternative supply to sustain plant operations, we may be required to stop production. A production halt for an extended period of time could result in material losses.

We rely on information technology in our operations and financial reporting and any material failure, inadequacy, interruption or security breach of that technology could harm our ability to efficiently operate our business and report our financial results accurately and timely.

We rely heavily on information technology systems across our operations, including for management of inventory, purchase orders, production, invoices, shipping, accounting and various other processes and transactions. Our ability to effectively manage our business, coordinate the production, distribution and sale of our products and ensure the timely and accurate recording and disclosure of financial information depends significantly on the reliability and capacity of these systems. While we have taken appropriate precautions to protect our systems, and to date, we have not experienced any material adverse events related to a security breach or cyber-attack, the failure of these systems to operate effectively, problems with transitioning to upgraded or replacement systems, or a breach in security of these systems through a cyber-attack or otherwise could cause delays and/or interruptions in plant operations, product sales, reduced efficiency of our operations and delays in reporting our financial results. Significant capital investments could be required to remediate any such problem. Security breaches of employee information or other confidential or proprietary data could also adversely impact our reputation and could result in litigation against us or the imposition of penalties.

We are exposed to potential business disruption from factors outside our control, including natural disasters, severe weather conditions, accidents, pandemic diseases, wars and other conflicts, tariffs, and unforeseen operational failures any of which could negatively affect our transportation operations and could adversely affect our cash flows and operating results.

Potential business disruption in available transportation due to natural disasters, severe weather conditions, international wars and other conflicts, the outbreak of a pandemic disease, significant track damage resulting from a train derailment, strikes or other interruptions by our transportation providers could result in delays in procuring and supplying raw materials to our ethanol facilities, or transporting ethanol and distillers grains to our customers. Such business disruptions may result in our inability to meet customer demand or contract delivery requirements, as well as the potential loss of customers.

We ship much of our products and receive a portion of our corn via rail, which involves risks involving potential regulatory changes that could adversely affect our cash flows and operating results.

A large portion of our ethanol and distillers grains sales are shipped via rail. In addition, we receive some corn via rail. Given the notoriety of recent major train derailments, it is possible that additional regulations could be enacted. Any changes to existing laws and regulations, or new laws and regulations, including voluntary measures taken by the rail industry, could result in higher shipping costs, or new requirements for the design, construction or operation of tank cars that transport hazardous materials, such as ethanol. In addition, any derailments involving our products could result in legal claims being brought against us that could involve significant liabilities.

We operate in a capital intensive industry. Limitations on external financing could adversely affect our financial performance.

We may need to incur additional financing to fund growth of our business or in times of increasing liquidity requirements (such as increases in raw material costs). Bankruptcy filings by several ethanol companies in past years and capital market volatility has reduced available capital for the ethanol industry. Any delays in obtaining additional financing, or our inability to do so, could have a material adverse impact on our financial results.

There is a risk of a pandemic that could spread into the United States and other countries.

During the early months of 2020, a new strain of COVID-19 spread into the United States and other countries. In an effort to contain the spread of this virus, there were various government mandated restrictions, in addition to voluntary privately implemented restrictions, including limiting public gatherings, retail store closures, restrictions on employees working and the quarantining of people who may have been exposed to the virus. The above actions led to reduced demand for ethanol. If in the future, this or other viruses surface, it could lead to prolonged production stoppages at our ethanol plants and could result in an adverse material impact on the results of operations and on our financial position.

Risks Related to our Former Refined Coal Operations

We believe our refined coal production company qualified to earn tax credits under IRC Section 45 through November 18, 2021. Although this operation has ceased, it remains subject to various risks and uncertainties. These include, but are not limited to, the risks and uncertainties as set forth below.

Our refined coal operation and its by-products may result in environmental and product liability claims and environmental compliance costs.

The construction and operation of refined coal operations were subject to Federal, state and local laws, regulations and potential liabilities arising under or relating to the protection or preservation of the environment, natural resources and human health and safety. Such laws and regulations generally require the operations and/or the utilities at which the operations are located to obtain and comply with various environmental registrations, licenses, permits, inspections and other approvals. Such laws and regulations also impose liability, without regard to fault or the legality of a party’s conduct, on certain entities that are considered to have contributed to, or are otherwise involved in, the release or threatened release of hazardous substances into the environment. Such risk remains even after production ceases at an operation to the extent the environmental damage can be traced to the types of chemicals or compounds used or operations conducted in connection with the use of refined coal.

Our insurance may not cover all environmental risk and costs or may not provide sufficient coverage in the event of an environmental claim. If significant uninsured losses arise from environmental damage or product liability claims, or if the costs of environmental compliance increase for any reason, our results of operations and financial condition could be adversely affected.

We used patented technology.

As part of the operations, we paid a license fee for patented technology. If we or our third-party operator are subject to patent infringement claims, we may incur legal fees to defend our position and be subject to additional costs and fees.

Risks Related to REX and General Risk Factors

We have concentrations of cash deposits at financial institutions that exceed federal insurance limits.

We generally have cash deposits that exceed federal insurance limits. Should the financial institutions we deposit our cash in experience insolvency or other financial difficulty, our access to cash deposits could be limited. In extreme cases, we could lose our cash deposits entirely. This would negatively impact our liquidity and results of operations.

We may fail to realize the anticipated benefits of mergers, acquisitions, or other investments.

We intend to continue seeking growth opportunities. Acquisitions and similar transactions involve many risks that could harm our business, which include:

	●	The anticipated benefits of these transactions may not be fully realized, or take longer to realize than expected,
	●	Future acquisitions could result in operating losses or loss of investment,
	●	Future acquisitions may involve incurring debt to complete these transactions, which could have a material adverse effect on our financial condition,
	●	Future acquisitions may require us to invest a significant portion of our excess cash, which could have a material adverse effect on our financial condition,
	●	Our carbon sequestration investment may not be successful, and
	●	Our projects to reduce the carbon intensity scores at our ethanol plants may not prove to be successful.

Rising focus on environmental, social and corporate governance matters from investors and regulators may increase our operating costs, bring down the value of our products and assets, and impact our ability to access capital markets.

Global climate change continues to receive significant attention from the public and the scientific community concerning the impacts from human activity, particularly the impact of greenhouse gas emissions, such as those from carbon dioxide and methane. Added requirements to reduce greenhouse gas emissions may increase our production costs. In addition, legislation promoting alternatives to combustion engine vehicles could reduce the demand for our products.

Climate change is also thought by some to be the cause for an increase in extreme weather events such as increased intensity of storms, rising sea levels, as well as heavy rains or droughts in areas historically less prone to those events. Any of these events can have a significant impact on our operations or quality of raw materials we purchase, resulting in increased costs. At this time, we are unable to determine the financial impact of any potential adverse weather events caused by climate change.

In recent past years, certain institutional investors adopted environmental, social and governance guidelines (ESG), and encouraged additional consideration of ESG practices in a manner that could negatively impact our stock price if continued in the future. This may also result in a reduction of available capital funding for potential development projects, further impacting our future financial results.

Federal, state and local jurisdictions may challenge our tax return positions.

We use significant judgments, estimates and interpretation and application of complex tax laws in preparing the tax returns we file, and the positions contained therein. We believe that our tax return positions are fully supportable. However, certain positions may be successfully challenged by federal, state and local jurisdictions. We are currently in the process of finalizing a federal income examination related to tax credits claimed for the years ended January 31, 2015 through 2022 and believe our financial statements reflect the agreed upon outcome of the examination.

Item 1B.

Unresolved Staff Comments

None.

Item 1C.

Cybersecurity

Our ability to effectively manage our business, coordinate the production, distribution and sale of our products and ensure the timely and accurate recording and disclosure of financial information depends significantly on the reliability and capacity of our information technology systems. While we have taken what we believe are appropriate precautions to protect our systems, and to date, we have not experienced any material adverse events related to a security breach or cyber-attack, the failure of these systems to operate effectively, the failure of our personnel to follow established procedures, problems with transitioning to upgraded or replacement systems, or a breach in security of these systems through a cyber-attack or otherwise could cause delays and/or interruptions in plant operations, product sales, reduced efficiency of our operations and delays in reporting our financial results.

As part of our routine and periodic overall risk management system or processes, we have incorporated various processes related to cybersecurity. Key cybersecurity controls, such as access controls, are included within our internal control framework that we assess annually as part of Management’s Annual Report on Internal Control Over Financial Reporting. Additionally, periodic discussions are held with outsourced IT professionals for both corporate and consolidated plant environments to determine if appropriate actions are being taken to address potential risks. Through the assistance of our qualified third-party IT professionals, we have implemented numerous security measures, including, but not limited to, multi-factor authentication on critical systems, password requirements, access controls, and data encryption. Our IT policies and procedures include the expectations of all employees and all third parties who may be given access to our IT systems to maintain the security of our IT systems.

Our commitment to the overall security of our information technology systems starts at the highest levels of our Company, the Board of Directors and management. Management and the Board of Directors provide oversight surrounding cybersecurity. Management oversees internal controls and the company-wide risk assessment process. The Audit Committee is provided with regular updates by management regarding the control framework and whether any significant deficiencies or material weaknesses exist in the IT control environment. The Audit Committee is also tasked with determining the appropriate response to any submissions through the corporate whistleblower policy. The whistleblower policy includes the opportunity for employees of the Company to notify the Audit Committee confidentially and anonymously of any concerns regarding cybersecurity, in addition to any accounting, internal accounting controls or auditing matters. The audit committee will report any significant matters to the Board of Directors.

As of January 31, 2026, we had not identified an indication of a cybersecurity incident that would have a material impact on our business and consolidated financial statements.

Item 2.

Properties

The information required by this Item 2 is set forth in Item 1 of this report under “Ethanol Investments” and “Facilities”.

Item 3.

Legal Proceedings

We are, from time to time, involved in various legal proceedings incidental to the conduct of our business. We believe that any current proceedings will not have a material adverse effect on our financial condition or results of operations.

Item 4.

Mine Safety Disclosures

Not Applicable.

Information About Our Executive Officers

Set forth below is certain information about each of our executive officers.

Name	Age	Position

Stuart Rose	71	Executive Chairman of the Board*
Zafar Rizvi	76	Chief Executive Officer and President*
Douglas Bruggeman	65	Vice President-Finance, Chief Financial Officer and Treasurer
Edward Kress	76	Secretary*

*Also serves as a director.

Stuart Rose was elected our Executive Chairman of the Board in 2015. Mr. Rose had served as our Chairman of the Board and Chief Executive Officer since our incorporation in 1984 as a holding company. Prior to 1984, Mr. Rose was Chairman of the Board and Chief Executive Officer of Rex Radio and Television, Inc., which he founded in 1980 to acquire the stock of a corporation which operated four retail stores.

Zafar Rizvi was elected Chief Executive Officer in 2015. Mr. Rizvi has been our President and Chief Operating Officer since 2010, was Vice President from 2006 to 2010, and from 1991 to 2006, Mr. Rizvi was our Vice President – Loss Prevention.

Douglas Bruggeman has been our Vice President–Finance and Treasurer since 1989 and was elected Chief Financial Officer in 2003. From 1987 to 1989, Mr. Bruggeman was our Manager of Corporate Accounting. Mr. Bruggeman was employed with the accounting firm of Ernst & Young prior to joining us in 1986.

Edward Kress has been our Secretary since 1984. Mr. Kress has been a partner of the law firm of Dinsmore & Shohl LLP (formerly Chernesky, Heyman & Kress P.L.L.), our legal counsel, since 1988. Mr. Kress has practiced law in Dayton, Ohio since 1974.

PART II

Item 5.

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

Shareholder Information

Our common stock is traded on the New York Stock Exchange under the symbol REX.

As of March 27, 2026, there were 58 holders of record of our common stock, including shares held in nominee or street name by brokers which, in turn, hold shares of stock for numerous beneficial owners.

Dividend Policy

The Company has no history of paying cash dividends on our common stock.

Issuer Purchases of Equity Securities

On March 25, 2025, the Board of Directors authorized the repurchase from time to time of up to an additional 3,000,000 shares through open market transactions, privately negotiated transactions, or transactions by other means in accordance with applicable securities laws. At January 31, 2026, a total of 2,357,186 shares remained available to purchase under this authorization.

There were no share repurchases in the fourth quarter of fiscal year 2025.

Equity Compensation Plans

Refer to Item 12 – Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters for information regarding shares authorized for issuance under equity compensation plans.

Performance Graph

The following graph compares the yearly percentage change in the cumulative total shareholder return on our Common Stock against the cumulative total return of the S&P 500 Stock Index and a peer group comprised of Alto Ingredients, Inc. and Green Plains, Inc. for the period commencing January 31, 2021 and ended January 31, 2026. The graph assumes an investment of $100 in our Common Stock and each index on January 31, 2021 and reinvestment of all dividends.

Item 6.

[Reserved]

Item 7.

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

Overview

We have been an investor in ethanol production facilities beginning in 2006. We currently have equity investments in three ethanol production entities, two of which are majority ownership interests. We may make additional alternative energy investments in the future and are currently working on a carbon sequestration project near our One Earth Energy location.

Our ethanol operations are highly dependent on commodity prices, especially prices for corn, ethanol, distillers grains, distillers corn oil and natural gas, and availability of corn. As a result of price volatility for these commodities, our operating results can fluctuate substantially. The price and availability of corn is subject to significant fluctuations depending upon several factors that affect commodity prices in general, including crop conditions, the amount of corn stored on farms, weather, federal policy, foreign trade, tariffs, and international disruptions caused by wars or conflicts. Because the market prices of ethanol and distillers grains are not always directly related to corn prices (for example, demand for crude and other energy and related prices, the export market demand for ethanol and distillers grains, soybean meal prices, and the results of federal policy decisions, trade negotiations, and tariffs can impact ethanol and distillers grains prices), at times ethanol and distillers grains prices may not follow movements in corn prices and, in an environment of higher corn prices or lower ethanol or distillers grains prices, reduce the overall margin structure at the plants. As a result, at times, we may operate our plants at negative or minimally positive operating margins.

We attempt to manage the risk related to the volatility of commodity prices by utilizing forward corn and natural gas purchase contracts, forward ethanol, distillers grains and distillers corn oil sale contracts, and commodity futures agreements, as management deems appropriate. We attempt to match quantities of these sales contracts with an appropriate quantity of corn purchase contracts over a given period of time when we can obtain an adequate gross margin resulting from the crush spread inherent in the contracts we have executed. However, the market for future ethanol sales contracts generally lags the spot market with respect to ethanol prices. Consequently, we generally execute fixed price contracts for no more than four months into the future at any given time and we may lock in our corn or ethanol price without having a corresponding locked in ethanol or corn price for short durations of time. As a result of the relatively short period of time our fixed price contracts cover, we generally cannot predict the future movements in our realized crush spread for more than four months; thus, we are unable to predict the likelihood or amounts of future income or loss from the operations of our ethanol facilities.

One Earth Sequestration, LLC, a wholly owned subsidiary of One Earth Energy, LLC, is in the developmental stage of a carbon sequestration project near the One Earth Energy ethanol plant. In October 2022, we applied to the EPA for a Class VI injection well permit for three wells, and we continue to provide information to the EPA during the technical review of our application. We currently expect the EPA to prepare a draft permit by May 2026 and make a final permit decision during the third quarter of 2026, according to the EPA’s Class VI Permit Tracker Dashboard on their website. We also must obtain certain state and county permits for the sequestration site and connector pipeline. We have completed the construction of the capture and compression facility to capture, dehydrate, and compress carbon dioxide from the One

Earth ethanol plant to a state suitable for sequestration. Testing has not yet been completed and we cannot begin construction of the CO₂ connector pipeline between the One Earth ethanol plant and the sequestration site or a sequestration well until further permits and approvals are received.

Although we have made meaningful progress and significant investments in the carbon sequestration project at One Earth Energy, we continue to work with the various government agencies involved to obtain all required permits and approvals, with no assurance of the ultimate success or timing of the project. Also see the discussion under “Trends and Uncertainties” on pages 25 and 26 of certain recently proposed legislation that, if enacted, could impact our carbon sequestration project.

We are also expanding the One Earth ethanol plant. We received a construction permit from the EPA to increase production from 150 million gallons of ethanol per year to 175 million gallons of ethanol per year. Once we achieve that level of production, we intend to apply for another permit to 200 million gallons per year. We continue to work to identify ways to reduce our CI score at the One Earth plant with the intention of maximizing tax credits available under the IRA.

The IRA created a new Clean Fuel Production Credit, available for calendar years 2025 – 2027 which, based on proposed rulemaking by the United States Department of Treasury, established a tax credit that utilizes a sliding scale where credits can be earned incrementally between $0.02 and $0.20, or $0.10 and $1.00 if prevailing wage and apprenticeship requirements are met, per gallon of non-SAF fuels based on an ethanol plant’s GHG reduction below a 50 CI score threshold, with the first two or ten cents earned upon achieving a CI score below 47.5, to incentivize further increases in plant efficiencies within the industry. In July 2025, Congress passed the OBBBA, which was subsequently signed into law by the President. The law extended the time period which 45Z credits can be claimed by two years, through December 31, 2029. The U.S. Department of the Treasury issued proposed rules on February 3, 2026 on qualification for 45Z tax credits. Based on these proposed regulations, we recognized approximately $28.1 million in 45Z tax credits through our consolidated subsidiaries for fiscal 2025.

We currently budget capital expenditures for both the expansion and sequestration projects at One Earth to be approximately $220 million to $230 million, subject to further refinement as we move forward. We plan to pay for all expenditures from available cash. As of January 31, 2026, we had spent $58.4 million since inception toward the carbon sequestration project and were contractually committed to spend an additional $0.6 million. If the carbon sequestration project is successful, we believe we will qualify for tax credits under section 45Q, based on tons of carbon sequestered, and section 45Z, based on gallons of ethanol produced, as provided in the IRA and OBBBA. Companies may elect either the 45Q credit or the 45Z credit in periods in which both tax credits are available. As of January 31, 2026, we had spent $107.6 million since inception and were contractually committed to spend an additional $15.5 million toward plant capacity expansion and ongoing efforts to reduce our CI scoring at One Earth.

In May 2023, NuGen, our majority owned ethanol plant in Marion, South Dakota, signed an agreement to be part of Summit Carbon Solutions’ carbon capture and storage pipeline. Should Summit Carbon Solutions be able to obtain all necessary permits and approvals, the agreement would allow NuGen to share in the economic benefits of tax credits through the sale of the CO₂ output of its ethanol production facility for sequestration, as well as to reduce its net carbon emissions. In March 2025, South Dakota enacted a law that bans the use of eminent domain in connection with CO₂ pipelines. In addition, in March 2026, a North Dakota Court voided the permits issued to Summit Carbon Solutions for underground storage of carbon dioxide as the Court has deemed the law the permits were issued under to be unconstitutional. Summit Carbon Solutions is analyzing the decision and is contemplating next steps. These actions could make the sequestration project for the NuGen facility more difficult for Summit Carbon Solutions to complete.

Ethanol Investments

In fiscal year 2006, we entered the ethanol industry by investing in several entities organized to construct and subsequently operate ethanol producing plants. We are invested in three entities as of January 31, 2026, utilizing equity investments.

The following table is a summary of our ethanol entity ownership interests at January 31, 2026:

Entity	Location	REX’s Current Ownership Interest
One Earth Energy, LLC	Gibson City, IL	76.1%
NuGen Energy, LLC	Marion, SD	99.7%
Big River Resources, LLC: Big River Resources W Burlington, LLC Big River Resources Galva, LLC Big River United Energy, LLC Big River Resources Boyceville, LLC	W. Burlington, IA Galva, IL Dyersville, IA Boyceville, WI	10.3% 10.3% 5.7% 10.3%

Trends and Uncertainties

Renewable Fuel Standard II, established in October 2010, has been an important factor in the growth of ethanol usage in the United States. There has been much uncertainty in the enforcement of RFS II. When it was originally established, RFS II required the volume of “conventional” or corn derived ethanol to be blended with gasoline to increase each year until it reached 15.0 billion gallons in 2015 and required that it remain at that level through 2022. There are no established congressional target volumes beginning in 2023. The EPA has the authority to waive the biofuel mandate, in whole or in part, if there is inadequate domestic renewable fuel supply or the requirement severely harms the domestic economy or environment. In addition, under RFS II, a small refiner that processes fewer than 75,000 barrels of oil per day can petition the EPA for a waiver of their requirement to submit RINs. The EPA, through consultation with the United States Department of Energy and the USDA, can grant the refiner a full or partial waiver, or deny the waiver. The EPA has the authority to waive the biofuel mandate, in whole or in part, if there is inadequate domestic renewable fuel supply or the requirement severely harms the domestic economy or environment. In addition, under RFS II, a small refiner that processes fewer than 75,000 barrels of oil per day can petition the EPA for a waiver of their requirement to submit RINs. The EPA, through consultation with the United States Department of Energy and the USDA, can grant the refiner a full or partial waiver, or deny the waiver. The waiving of a refiner’s obligation effectively lowers the amount of renewable fuels required to be blended, and by extension the amount of RINs that need to be retired, which can impact their values and ultimately blending levels of renewable fuels. There are multiple ongoing legal challenges to how the EPA has handled SREs and RFS rulemaking. On August 22, 2025, the EPA ruled on much of the backlog of SREs, issuing 63 full exemptions, 77 partial exemptions of 50%, 28 denials and 7 ruled as ineligible. On November 7, 2025, the EPA issued two 100% waivers, twelve 50% waivers and two denials. As of March 19, 2026, there were 37 SRE petitions pending from compliance years 2023-2025.

The EPA has issued RVOs for calendar years 2023-2025. The volumes from conventional biofuels (which includes corn-based ethanol) were 15.0 billion gallons for 2023 through 2025. Additionally, in 2023, the EPA restored 250 million gallons previously waived. On March 27, 2026, the EPA issued total RVOs for 2026 and 2027 of 15.0 billion gallons of conventional ethanol for each year.

The EPA recently issued emergency waivers allowing the sale of E-15 gasoline for the 2026 summer months. 2026 will represent the fifth consecutive year for these emergency waivers. The EPA has not granted E-15 the same Reid vapor pressure waiver as E-10, so absent the emergency waivers, E-15 may not be sold in most states from June 1 to September 15.

The IRA, signed into law on August 16, 2022, created a new Clean Fuel Production Credit, section 45Z, originally available for years 2025 to 2027. Based on proposed rulemaking by the United States Department of Treasury, the Clean Fuel Production Credit will be established utilizing a sliding scale where tax credits may be earned incrementally between $0.02 and $0.20, or $0.10 and $1.00 if prevailing wage and apprenticeship requirements are met, per gallon of non-SAF fuels based on a plant’s GHG reduction below a 50 CI score threshold, with the first two or ten cents earned upon achieving a CI score

below 47.5. The IRA also raises the carbon capture tax credit from $50 per metric ton to $85 per metric ton, under section 45Q. Companies may elect either the 45Q credit or the 45Z credit in periods in which both tax credits are available.

The OBBBA introduced major revisions to clean energy tax credits. Key provisions include extending the 45Z credit through 2029, removing the indirect land-use change penalty for crop-based feedstocks, limiting eligibility to feedstocks under the USMCA, imposing FEOC restrictions, and prohibiting negative emissions rates except from animal manure. It also modified the language for 45Q tax credits for facilities placed in service after the bill enactment but maintained the $85 per ton tax credit if the prevailing wage and apprenticeship requirements are met. 45Q credits are available for 12 years from the time CO₂ injection begins.

We have secured land easements from all necessary landowners to allow the construction of the CO₂ connector pipeline on their land from the ethanol plant to the first two injection wells for our carbon sequestration project near the One Earth Energy ethanol facility. We also have landowner subsurface easements for the first injection well with capacity sufficient to allow for carbon sequestration for our One Earth plant for an estimated 15 years. The Illinois General Assembly passed the Safety and Aid for the Environment in Carbon Capture and Sequestration Act (SB 1289), which was signed by the Governor in July 2024. The legislation imposes additional safety, environmental and other requirements on obtaining permits and approvals for carbon capture and sequestration facilities in Illinois, including CO₂ pipelines. Further, the legislation imposes a moratorium on the issuance of new certificates of authority for the construction of CO₂ pipelines until the earlier of the date new federal CO₂ pipeline safety standards are finalized by the federal PHMSA or, subject to certain other conditions, July 1, 2026.

Illinois Senate Bill 1723 was signed into law by the Governor on August 1, 2025. SB 1723 prohibits carbon sequestration activities over, under, or through an aquifer as defined by the EPA. The proposed injection wells for our carbon sequestration project are located outside of these areas.

Although we have made meaningful progress and significant investments in the carbon sequestration project at One Earth, we continue to work with the various government agencies involved to obtain all required permits and approvals, with no assurance of the ultimate success or timing of the project.

The United States exported an estimated 2.2 billion gallons of ethanol in 2025, up from approximately 1.9 and 1.4 billion gallons in 2024 and 2023, respectively. In 2025 and 2024, an estimated 11.6 and 12.1 million metric tons, respectively, of distillers grains were exported from the United States, which represented approximately 36% and 37% in 2025 and 2024, respectively, of U.S production. There has been much discussion around proposed and recently enacted tariffs by the United States and counter-tariffs and other trade restriction involving countries which have been large purchasers from our industry in the United States.

Should these trends and uncertainties continue, our future operating results could be impacted.

Results of Operations

The following table summarizes our results from operations (amounts in thousands):

	Fiscal Year
		2025		2024

Net sales and revenue	$	650,487	$	642,491
Cost of sales		556,781		551,014
Gross profit	$	93,706	$	91,477

Income before income taxes	$	88,572	$	92,872

Benefit (provision) for income taxes	$	6,502	$	(21,386)

Net income attributable to REX common shareholders	$	82,951	$	58,167

The following table summarizes net sales and revenue by product group (amounts in thousands):

	Fiscal Year
		2025		2024

Ethanol	$	504,416	$	496,411
Dried distillers grains		88,156		101,432
Distillers corn oil		52,382		38,999
Modified distillers grains		5,388		4,896
Derivative financial instruments (losses) gains		(254)		424
Other		399		329
Total	$	650,487	$	642,491

The following table summarizes selected operating data:

	Fiscal Year
		2025		2024

Average selling price per gallon of ethanol (net of hedging)	$	1.74	$	1.71
Gallons of ethanol sold (in millions)		290.0		289.7
Average selling price per ton of dried distillers grains	$	144.06	$	160.37
Tons of dried distillers grains sold		611,929		632,469
Average selling price per pound of distillers corn oil	$	0.54	$	0.44
Pounds of distillers corn oil sold (in millions)		97.0		88.1
Average selling price per ton of modified distillers grains	$	65.82	$	69.93
Tons of modified distillers grains sold		81,861		70,013

Comparison of Fiscal Years 2025 and 2024 (Consolidated Results)

Net Sales and Revenue – Net sales and revenue in the year ended January 31, 2026 increased approximately 1%, or $8.0 million, compared to the year ended January 31, 2025.

Ethanol sales increased in fiscal year 2025 compared to fiscal year 2024 as the average price per gallon increased 2%, along with gallons sold remaining steady compared to the prior period. Ethanol pricing is affected by many factors, including overall market supply and demand, as well as corn and gasoline pricing.

Dried distillers grains sales decreased in fiscal year 2025 compared to fiscal year 2024, decreasing 13% year-over-year, as the average price per ton sold decreased 10%, as well as a decrease in tons sold of 3%. The decrease in the dried distillers grains selling price is consistent with recent quarters and reflects an extended period of lower corn pricing as dried distillers grains prices often correlate with corn pricing. The decrease in tons sold was impacted by increased production levels of other ethanol by-products.

Distillers corn oil sales increased 34% in fiscal year 2025 compared to fiscal year 2024 as the average selling price per pound increased approximately 23% and the amount of pounds sold increased 10%. The corn oil yield per bushel ground improved at our consolidated ethanol plants in fiscal 2025 relative to the comparable period in fiscal 2024. The increase in the distillers corn oil selling price resulted primarily from fluctuations in demand in the renewable biodiesel market.

Modified distillers grains sales increased 10% in fiscal year 2025 compared to fiscal year 2024 as the amount of tons sold increased 17%, offset partially by a 6% decrease in the average selling price per ton sold. The decrease in the modified distillers grains selling price resulted primarily from an extended period of lower corn prices, as prices tend to move in the same direction but are also impacted by changes in local market demand. Our consolidated plants’ decisions to sell modified or dried distillers grains fluctuate from time to time based upon market conditions.

Losses on derivative financial instruments were $0.3 million in fiscal year 2025, compared to gains of $0.4 million in fiscal year 2024. Gains and losses are related to our risk management activities and were impacted by the price movements and types of contracts entered into at our consolidated ethanol plants.

Cost of Sales – Cost of sales for fiscal year 2025 increased approximately $5.8 million, or 1%, over fiscal year 2024. Corn accounted for approximately 74% ($411.5 million) of our cost of sales during fiscal year 2025 compared to approximately 76% ($416.4 million) during fiscal year 2024. The cost of corn decreased due to lower corn prices, while the amount of bushels used remained stable year over year. Natural gas accounted for approximately 5% ($29.0 million) of our cost of sales during fiscal year 2025 compared to approximately 4% ($22.6 million) during fiscal year 2024.

Gross Profit – As a result of the foregoing, gross profit for fiscal year 2025 increased approximately $2.2 million, or 2%, from fiscal year 2024. Gross profit in fiscal year 2025 was approximately 14.4% of net sales and revenue, versus approximately 14.2% of net sales and revenue in fiscal year 2024.

We attempt to match quantities of ethanol, distillers grains and distillers corn oil sale contracts with an appropriate quantity of grain purchase contracts over a given period of time when we can obtain an adequate margin resulting from the crush spread inherent in the contracts we have executed. However, the market for future ethanol sales contracts generally lags the spot market with respect to ethanol price. Consequently, we generally execute fixed price contracts for no more than four months into the future at any given time and we may lock in our corn or ethanol price without having a corresponding locked in ethanol or corn price for short durations of time. As a result of the relatively short period of time our fixed price contracts cover, we generally cannot predict the future movements in our realized crush spread for more than four months. We utilize derivative financial instruments, primarily exchange traded commodity future contracts and swaps, in conjunction with our grain procurement and commodity marketing activities.

Selling, General and Administrative (“SG&A”) Expenses – SG&A expenses for fiscal year 2025 were approximately $32.6 million (5.0% of net sales and revenue), an increase of approximately $5.5 million or 20% from approximately $27.1 million (4.2% of net sales and revenue) for fiscal year 2024. The dollar increase compared to the prior year is primarily related to a $2.0 million increase in performance bonuses due to the increase in net income and recording unpaid stock bonuses at fair value. Additionally, there was a $1.4 million increase related to the lease of railcars. Approximately $1.1 million was accrued in fiscal 2025 for costs associated with 45Z tax credits, including the planned purchase of EACs.

Equity in Income of Unconsolidated Ethanol Affiliates – During fiscal years 2025 and 2024, we recognized income of approximately $12.5 million and $9.4 million, respectively, from our equity investment in Big River Resources, LLC (“Big River”). Our investment in Big River, which has interests in four ethanol production plants, represents an effective ownership of approximately 38.6 million gallons of ethanol shipped in the trailing twelve months ended January 31, 2026.

We expect the operating experience of Big River to be generally consistent with the trends in crush spread margins described in the “Overview” section as Big River’s results are dependent on the same industry dynamics as our other ethanol investments (ethanol, corn, dried distillers grains and natural gas pricing).

Interest and Other Income – Interest and other income for fiscal year 2025 was approximately $15.0 million compared to approximately $19.2 million for fiscal year 2024. The decrease is primarily related to decreased interest income of $4.6 million in fiscal year 2025 based upon lower average balances and yields on our excess cash and short-term investments in fiscal year 2025, compared to 2024. One of our consolidated ethanol plants recognized $0.5 million less in patronage income from an investment in a cooperative in fiscal 2025 ($0.7 million) compared to fiscal 2024 ($1.2 million). We do not expect patronage income from this investment in a cooperative to be significant in future periods. These decreases in interest and other income were partially offset by $1.2 million in interest income recorded in fiscal 2025, owed from the IRS as part of the finalization of the IRS audit over refined coal and research and experimentation tax credits.

Income Before Income Taxes – As a result of the foregoing, income before income taxes was approximately $88.6 million for fiscal year 2025 versus approximately $92.9 million for fiscal year 2024.

Provision for Income Taxes – Our effective tax rate was a benefit of 7.3% and a provision of 23.0% for fiscal years 2025 and 2024, respectively. Our effective rate is impacted by the noncontrolling interests of the companies we consolidate, as we recognize 100% of their income or loss before income taxes and noncontrolling interests and only provide an income tax provision or benefit for our portion of the subsidiaries’ income or loss. During fiscal 2025, our effective tax rate decreased by 31.8% (approximately $28.1 million) as a result of 45Z tax credits earned by our ethanol facilities as a result of their qualified ethanol production after the purchase of EACs. During both fiscal years 2025 and 2024, our effective tax rate increased 2.7% and 2.2%, respectively (approximately $2.4 million and $2.1 million, respectively), as a result of section 162M compensation limitations. The impact of the effective settlement of the IRS audits during fiscal 2025 related

to the refined coal tax credits and the research and experimentation credits resulted in an increase to our effective tax rate of 1.3% (approximately $1.2 million).

Net Income – As a result of the foregoing, net income was approximately $95.1 million for fiscal year 2025 versus approximately $71.5 million for fiscal year 2024.

Net Income Attributable to Noncontrolling Interests – Income attributable to noncontrolling interests was approximately $12.1 million and $13.3 million during fiscal years 2025 and 2024, respectively, and represents the other owners’ share of the income of NuGen and One Earth.

Net Income Attributable to REX Common Shareholders – As a result of the foregoing, net income attributable to REX common shareholders was approximately $83.0 million for fiscal year 2025 compared to $58.2 million for fiscal year 2024.

Comparison of Fiscal Years 2024 and 2023

See “Item 7 Management’s discussion and Analysis of Financial Condition and Results of Operations” in our Annual Report on Form 10-K for the year ended January 31, 2025.

Liquidity and Capital Resources

Our primary sources of cash have been income from operations. Our primary uses of cash have been capital expenditures at our ethanol plants and carbon sequestration project, stock repurchases, and payments to noncontrolling interests holders.

Summary of Cash Flows and Working Capital (amounts in thousands):

	Year Ended January 31,
	2026		2025
Net cash provided by operating activities	$	117,829	$	64,192
Net cash used in investing activities	$	(87,691)	$	(72,860)
Net cash used in financing activities	$	(37,659)	$	(18,474)

	January 31, 2026		January 31, 2025
Working capital	$	372,451	$	385,376
Current ratio		5.9x		8.6x

Capital Resources

At January 31, 2026, working capital was $372.5 million with a current ratio of 5.9x. Our cash and short-term investments balance of approximately $375.8 million at January 31, 2026 included approximately $336.5 million held by One Earth and NuGen. We expect that One Earth and NuGen will use a majority of their cash for working capital needs, capital expenditures, general corporate purposes and dividend payments. We expect our equity method investee to limit the payment of dividends based upon their working capital and capital expenditure needs, as well as restricting dividends pursuant to the terms of various loan agreements. None of our consolidated subsidiaries or the parent company have restricted net assets related to loan agreements at January 31, 2026.

We are investigating various uses of our excess cash We expect total capital expenditures related to the construction at the One Earth facilities to approximate $220 million to $230 million, inclusive of the carbon sequestration project and

plant capacity expansion and ongoing efforts to reduce CI scoring, which we currently plan to pay from our available cash. This estimate is subject to further refinement as the projects progress. As of January 31, 2026, we had spent $58.4 million since inception and were contractually committed to spend an additional $0.6 million toward the carbon sequestration project. As of January 31, 2026, we had spent $107.6 million since inception and were contractually committed to spend an additional $15.5 million toward plant capacity expansion and CI scoring reduction efforts. For all projects, we plan to spend $70 million to $80 million during fiscal year 2026.

We have a stock buyback program in place. On March 25, 2025, the Board of Directors authorized the repurchase from time to time of up to an additional 3,000,000 shares through open market transactions, privately negotiated transactions, or transactions by other means in accordance with applicable securities laws. During fiscal year 2025, we purchased 1,651,252 shares for $32.9 million. After these repurchases, a total of 2,357,186 shares remained available to purchase under existing board authorization at January 31, 2026. Repurchases are generally made when management deems the shares are trading at a discount to intrinsic value.

We plan to seek and evaluate various investment opportunities including ethanol and/or energy related, carbon sequestration related, agricultural or other ventures we believe fit our investment criteria.

Operating Activities

Net cash provided by operating activities was $117.8 million for fiscal 2025, compared to $64.2 million for the prior year period.

Operating cash flows for the year ended January 31, 2026 reflected net income of $95.1 million and non-cash adjustments of $6.8 million, consisting of depreciation, noncash operating lease expense, amortization of finance right-of-use asset, income from equity method investments, interest income from short-term investments, the deferred income tax provision, stock-based compensation expense, and loss on disposal of property and equipment. Additionally, Big River paid dividends of approximately $10.5 million during fiscal year 2025. In addition, changes to working capital of $5.5 million increased cash during fiscal 2025, most significantly including:

	●	Cash provided of $8.4 million due to a increase in accounts payable, primarily related to the timing of inventory receipts and vendor payments
	●	Cash provided of $6.8 million from the decrease in accounts receivable as a result of the timing of products shipping and the receipt of customer payments at our consolidated ethanol plants
	●	Cash provided of approximately $3.3 million from the decrease of inventory balances during the period
	●	Use of cash of approximately $10.3 million from both the increase in income tax refundable and the decrease in long-term taxes payable as a result of the timing of estimated tax payments, payments made through dividend payment withholdings from our ethanol subsidiaries and the impact of the effective settlement of the uncertain tax positions related to the research and experimentation credits audited by the IRS
	●	Use of cash of approximately $2.5 million from the decrease in accrued expenses and other liabilities as a result a reduction in the lease liabilities from payments made during the year of approximately $6.1 million , offset partially by the accrual of expenses for prevailing wages and EACs of approximately $1.8 million as part of the recognition of 45Z tax credits, an increase in the accrual of the 2025 incentive bonuses to be paid in 2026 of approximately $1.5 million, and an increase in accrued utilities of approximately $0.8 million

In fiscal 2024, operating cash flow reflected net income of $71.5 million and non-cash adjustments of $20.2 million. Additionally, Big River paid dividends of approximately $8.5 million during fiscal year 2024. These inflows were partially offset by various changes to working capital of approximately $36.1 million, most significantly caused by:

	●	Use of cash of approximately $14.9 million due to the increase in the balance of prepaid expenses and other assets primarily related to prepayments on certain executed lease agreements, offset by a decrease in property taxes refundable due to the timing of payments, and decreases in spare parts inventory
	●	Use of cash of approximately $14.7 million due to a decrease in accounts payable, primarily related to the timing of inventory receipts and vendor payments

	●	Use of cash of approximately $7.0 million from the decrease in accrued expense and other liabilities as a result of operating lease payments of approximately $5.5 million, a decrease in accrued payroll and related items of $0.4 million, and other decreases of approximately $1.1 million
	●	Use of cash of approximately $4.7 million from the increase of inventory balances during the period
	●	Cash provided of approximately $4.3 million to reflect the increase in long-term taxes payable by the amount the recorded uncertain tax positions exceeded the remaining unused credits

Investing Activities

Net cash used by investing activities was $87.7 million in fiscal 2025 versus $72.9 million in fiscal 2024. In fiscal 2025, capital expenditures totaled $68.4 million, primarily at One Earth, which includes plant expansion and CI reduction projects ($43.7 million) and carbon sequestration ($3.0 million). Our two consolidated ethanol plants had a combined $21.7 million in capital expenditures during fiscal 2025 that were not included in the plant expansion, CI reduction, or carbon sequestration projects. Treasury activity used net cash, as purchases of $296.4 million exceeded $277.0 million of maturities.

During fiscal 2024, capital expenditures were $71.3 million, primarily at One Earth, which includes plant expansion and CI reduction projects ($34.9 million) and carbon sequestration ($26.6 million). Treasury activity used net cash, as purchases of $372.3 million were partially offset by $370.4 million of maturities.

Financing Activities

Net cash used in financing activities was approximately $37.7 million during fiscal year 2025 compared to approximately $18.5 million for fiscal year 2024. During fiscal year 2025, we purchased approximately 1,651,000 shares of our common stock for approximately $32.9 million in open market transactions. During fiscal year 2025, we also used cash of approximately $4.1 million to purchase shares from and pay dividends to noncontrolling members of the consolidated entities and approximately $0.2 million for finance lease payments.

Net cash used in financing activities was approximately $18.5 million during fiscal year 2024, which was used to purchase approximately 745,000 shares of our common stock for approximately $15.5 million in open market transactions, of which $0.8 million was paid subsequent to January 31, 2025. During fiscal year 2024, we used cash of approximately $3.7 million to purchases shares from and pay dividends to noncontrolling members of the consolidated entities.

Based on our forecasts, which are primarily based on estimates of plant production, prices of ethanol, corn, distillers grains, distillers corn oil and natural gas as well as other assumptions, management believes that cash flow from operating activities together with working capital will be sufficient to meet One Earth’s and NuGen’s respective liquidity needs. However, if a material adverse change in the financial position of One Earth or NuGen should occur, or if actual sales or expenses are substantially different than what has been forecasted, One Earth’s and NuGen’s liquidity, and ability to fund future operating and capital requirements could be negatively impacted.

Approximately 2.4% of our net assets are restricted pursuant to the terms of various loan agreements of Big River, our equity method investee, as of January 31, 2026. None of our consolidated subsidiaries or the parent company have restricted net assets related to loan agreements at January 31, 2026.

Contractual Obligations and Commitments

In the ordinary course of business, we enter into agreements under which we are legally obligated to make future cash payments. These agreements include obligations related to purchasing inventory and natural gas and leasing rail cars. Aggregate minimum lease payments under the operating lease agreements for future fiscal years as of January 31, 2026 totaled $20.0 million, with $7.7 million payable in the next twelve months. Aggregate minimum lease payments under the finance lease agreements for future fiscal years as of January 31, 2026 totaled $4.3 million, with $0.5 million payable in the next twelve months. Refer to Note 7 – Leases included in the notes to consolidated financial statements for more information. As of January 31, 2026, we had contracted future payments for purchases of corn and natural gas, a natural gas pipeline lease, and other contracts for capital expenditures at our ethanol plants valued at approximately $123.0 million, with $108.3 million payable in the next twelve months. Refer to Note 11 – Commitments included in the notes to consolidated financial statements for more information.

Seasonality and Quarterly Fluctuations

Our business is directly affected by the supply and demand for ethanol. The demand for ethanol typically increases during the spring and summer months and during holiday travel.

Critical Accounting Policies

We believe the application of the following accounting policies, which are important to our financial position and results of operations, require significant assumptions, judgments and estimates on the part of management. We base our assumptions, judgments, and estimates on historical experience, current trends and other factors that management believes to be relevant at the time our consolidated financial statements are prepared. On a regular basis, management reviews the accounting policies, assumptions, estimates and judgments to ensure that our financial statements are presented in accordance with generally accepted accounting principles (GAAP). However, because future events and their effects cannot be determined with certainty, actual results could differ from our assumptions and estimates, and such differences could be material. Further, if different assumptions, judgments and estimates had been used, the results could have been different and such differences could be material. For a summary of all of our accounting policies, including the accounting policies discussed below, see Note 1 to the Consolidated Financial Statements.

Management believes that the following accounting policies are the most critical to aid in fully understanding and evaluating our reported financial results, and they require management’s most difficult, subjective, or complex judgments, resulting from the need to make estimates about the effect of matters that are inherently uncertain.

Revenue Recognition – We recognize sales of ethanol, distillers grains and distillers corn oil when obligations under the terms of the respective contracts with customers are satisfied; this occurs with the transfer of control of products, generally upon shipment from the ethanol plant or upon loading of the rail car used to transport the products.

Impairment of Long-Lived Assets – We review our long-lived assets, consisting of property and equipment, equity method investments and operating lease right-of-use assets, for impairment whenever events or changes in circumstances indicate the carrying amount of the asset may not be recoverable. We assess long-lived assets for impairment by first determining the forecasted, undiscounted cash flows the asset group is expected to generate. If this total is less than the carrying value of the asset, we will then determine the fair value of the asset group. An impairment loss would be recognized in the amount by which the carrying amount of the asset exceeded the fair value of the asset. Significant management judgement is required to determine the fair value of long-lived assets, which includes discounted cash flows. Such estimates could be significantly affected by future changes in market conditions. We recorded no impairment charges in fiscal year 2025, 2024, and 2023.

Income Taxes – Income taxes are recorded based on the current year amounts payable or refundable, as well as the consequences of events that give rise to deferred tax assets and liabilities based on differences in how those events are treated for tax purposes, net of valuation allowances. We base our estimate of deferred tax assets and liabilities on current tax laws and rates and other expectations about future outcomes. Changes in existing regulatory tax laws and rates and future business results may affect the amount of deferred tax liabilities or the valuation of deferred tax assets over time. We have established valuation allowances for certain state net operating loss carryforwards. We assessed all available positive and negative evidence to determine whether we expect sufficient future taxable income will be generated to allow for the realization of existing federal deferred tax assets. We believe there is sufficient objectively verifiable income for management to conclude that it is more likely than not that the Company will utilize available federal deferred tax assets prior to their expiration. However, realization of these deferred tax assets is not certain. Changes in our current estimates for factors such as unanticipated market conditions and legislative developments could have a material effect on our ability to utilize deferred tax assets.

New Accounting Pronouncements

For information related to recent accounting pronouncements, see Note 1 of the Notes to the Consolidated Financial Statements.

Item 7A.

Quantitative and Qualitative Disclosures About Market Risk

We are exposed to the impact of market fluctuations associated with commodity prices as discussed below.

Commodity Price Risk

We manage a portion of our risk with respect to the volatility of commodity prices inherent in the ethanol industry by using forward purchase and sale contracts. At January 31, 2026, One Earth and NuGen combined had purchase commitments for approximately 18.4 million bushels of corn, the principal raw material for their ethanol plants. At January 31, 2026, One Earth and NuGen combined had purchase commitments for approximately 1.7 million MmBtu of natural gas. At January 31, 2026, One Earth and NuGen had combined sales commitments for approximately 54.8 million gallons of ethanol, 107,000 tons of distillers grains and 17.0 million pounds of distillers corn oil. Not all of our commitments are at fixed price. Our exposures to market risk, which include the impact of our risk management activities, are based on the estimated effect on pre-tax income starting on January 31, 2026, are as follows (amounts in thousands):

Commodity	Estimated Total Volume for the Next 12 Months		Unit of Measure	Decrease in Pre-tax Income From a 10% Adverse Change in Price

Ethanol		308,000	Gallons		$	48,936
Corn		106,600	Bushels		$	41,199
Distillers Grains		750	Tons		$	8,500
Distillers Corn Oil		101,000	Pounds		$	4,430
Natural Gas		7,400	MmBtu		$	2,246

Item 8. Financial Statements and Supplementary Data
REX AMERICAN RESOURCES CORPORATION AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
(Amounts in Thousands)

	January 31,
ASSETS	2026		2025
CURRENT ASSETS:
Cash and cash equivalents	$	188,734	$	196,255
Short-term investments		187,048		162,820
Accounts receivable		14,682		21,511
Inventory		28,422		31,676
Refundable income taxes		12,374		6,445
Prepaid expenses and other		16,568		17,112
Total current assets		447,828		435,819
Property and equipment - net		272,029		210,683
Operating lease right-of-use assets		17,594		20,985
Finance lease right-of-use assets		17,558		-
Other assets		4,963		16,721
Equity method investments		37,759		35,800
TOTAL ASSETS	$	797,731	$	720,008
LIABILITIES AND EQUITY
CURRENT LIABILITIES:
Accounts payable – trade (includes $1.2 million and $1.4 million with related parties at January 31, 2026 and 2025, respectively)	$	38,400	$	28,337
Current operating lease liabilities		6,921		5,746
Current finance lease liabilities		469		-
Accrued expenses and other current liabilities		29,587		16,360
Total current liabilities		75,377		50,443
LONG-TERM LIABILITIES:
Deferred taxes		4,065		3,562
Long-term operating lease liabilities		11,148		15,367
Long-term finance lease liabilities		2,731		-
Long-term taxes payable		-		4,334
Other long-term liabilities		2,405		2,700
Total long-term liabilities		20,349		25,963
COMMITMENTS AND CONTINGENCIES (Notes 11 and 13) EQUITY:
REX shareholders’ equity:
Common stock, at $0.01 par value; 45,000 shares authorized; 32,938 and 34,389 shares issued at January 31, 2026 and 2025, respectively		329		344
Paid in capital		66		-
Retained earnings		610,317		559,993
Total REX shareholders’ equity		610,712		560,337
Noncontrolling interests		91,293		83,265
Total equity		702,005		643,602
TOTAL LIABILITIES AND EQUITY	$	797,731	$	720,008

See notes to consolidated financial statements.

REX AMERICAN RESOURCES CORPORATION AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF OPERATIONS
(Amounts in Thousands, Except Per Share Amounts)

	Years Ended January 31,
	2026		2025		2024

Net sales and revenue	$	650,487	$	642,491	$	833,384
Cost of sales (includes $86.4 million, $99.2 million and $117.0 million with related parties for the years ended January 31, 2026, 2025 and 2024, respectively)		556,781		551,014		735,166

Gross profit		93,706		91,477		98,218

Selling, general and administrative expenses		(32,616)		(27,148)		(29,379)
Equity in income of unconsolidated affiliates		12,485		9,385		13,921
Interest and other income, net		14,997		19,158		15,724

Income before income taxes		88,572		92,872		98,484
Benefit (provision) for income taxes		6,502		(21,386)		(22,560)

Net income		95,074		71,486		75,924
Net income attributable to noncontrolling interests		(12,123)		(13,319)		(14,989)
Net income attributable to REX common shareholders	$	82,951	$	58,167	$	60,935

Weighted average shares outstanding – basic		33,208		35,272		34,964

Basic net income per share attributable to REX common shareholders	$	2.50	$	1.65	$	1.74

Weighted average shares outstanding – diluted		33,208		35,272		35,151

Diluted net income per share attributable to REX common shareholders	$	2.50	$	1.65	$	1.73

See notes to consolidated financial statements.

REX AMERICAN RESOURCES CORPORATION AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF SHAREHOLDERS’ EQUITY

FOR THE YEARS ENDED JANUARY 31, 2026, 2025 AND 2024

(Amounts in Thousands)

	REX Shareholders
	Issued				Paid-in		Retained		Noncontrolling		Total
	Shares		Amount		Capital		Earnings		Interest		Equity

Balance at January 31, 2023		34,780	$	348	$	-	$	447,634	$	63,012	$	510,994

Net income								60,935		14,989		75,924
Capital contributions										22		22
Noncontrolling interests distribution and other										(4,344)		(4,344)
Issuance of equity awards and stock-based compensation expense		227		2		-		4,999		-		5,001

Balance at January 31, 2024		35,007		350		-		513,568		73,679		587,597

Net income								58,167		13,319		71,486
Stock repurchases		(745)		(7)				(15,515)				(15,522)
Noncontrolling interests distribution and other										(3,733)		(3,733)
Issuance of equity awards and stock-based compensation expense		127		1		-		3,773		-		3,774

Balance at January 31, 2025		34,389		344		-		559,993		83,265		643,602

Net income								82,951		12,123		95,074
Capital contributions										9		9
Stock repurchases		(1,651)		(16)				(32,869)				(32,885)
Noncontrolling interests distribution and other										(4,104)		(4,104)
Issuance of equity awards and stock-based compensation expense		320		3		66		2,621		-		2,690
Correction to equity awards and stock-based compensation expense		(120)		(2)		-		(2,379)		-		(2,381)

Balance at January 31, 2026		32,938	$	329	$	66	$	610,317	$	91,293	$	702,005

See notes to consolidated financial statements.

REX AMERICAN RESOURCES CORPORATION AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF CASH FLOWS

(Amounts in Thousands)

	Years Ended January 31,
	2026		2025		2024
CASH FLOWS FROM OPERATING ACTIVITIES:
Net income	$	95,074	$	71,486	$	75,924
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation		15,340		15,927		17,794
Noncash operating lease expense		6,398		5,788		5,245
Amortization of finance lease right-of-use assets		1,424		-		-
Stock-based compensation expense		4,205		3,638		6,209
Income from equity method investments		(12,485)		(9,385)		(13,921)
Dividends received from equity method investments		10,526		8,521		12,030
Interest income from investments		(4,842)		(5,576)		(10,008)
Loss on disposal of real estate and property and equipment		192		50		243
Deferred income tax		(3,472)		9,802		14,627
Changes in assets and liabilities:
Accounts receivable		6,829		1,674		1,977
Inventory		3,254		(4,692)		21,760
Prepaid expenses and other assets		(289)		(14,946)		(4,495)
Income taxes refundable		(5,929)		(717)		(2,766)
Accounts payable – trade		8,395		(14,724)		7,868
Long-term taxes payable		(4,334)		4,334		-
Accrued expenses and other liabilities		(2,457)		(6,988)		(4,517)
Net cash provided by operating activities		117,829		64,192		127,970
CASH FLOWS FROM INVESTING ACTIVITIES:
Capital expenditures		(68,439)		(71,318)		(37,663)
Purchases of short-term investments		(296,386)		(372,341)		(448,507)
Maturities of short-term investments		277,000		370,357		514,586
Proceeds from disposal of real estate and property and equipment		7		262		29
Deposits		127		180		(43)
Net cash (used in) provided by investing activities		(87,691)		(72,860)		28,402
CASH FLOWS FROM FINANCING ACTIVITIES:
Treasury stock acquired		(33,383)		(14,741)		-
Capital contributions from minority investor		9		-		22
Payments to noncontrolling interests holders		(4,104)		(3,733)		(4,344)
Principal paid on finance lease liabilities		(181)		-		-
Net cash used in financing activities		(37,659)		(18,474)		(4,322)
NET (DECREASE) INCREASE IN CASH AND CASH EQUIVALENTS		(7,521)		(27,142)		152,050
CASH AND CASH EQUIVALENTS-Beginning of year		196,255		223,397		71,347
CASH AND CASH EQUIVALENTS-End of year	$	188,734	$	196,255	$	223,397

Non-cash investing activities-Accrued capital expenditures	$	8,758	$	1,152	$	918
Non-cash investing activities-Capital additions transferred from prepaid expenses	$	839	$	217	$	-
Non-cash financing activities-Stock awards issued	$	-	$	2,172	$	965
Non-cash financing activities-Stock awards accrued	$	3,896	$	2,037	$	2,172
Non-cash financing activities-Stock repurchases accrued	$	-	$	781	$	-
Operating right-of-use assets acquired and liabilities incurred upon lease commencement	$	3,007	$	13,734	$	3,210
Finance right-of-use assets acquired and liabilities incurred upon lease commencement	$	3,381	$	-	$	-

See notes to consolidated financial statements.

REX AMERICAN RESOURCES CORPORATION AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

Principles of Consolidation – The accompanying financial statements consolidate the operating results and financial position of REX American Resources Corporation and its wholly-owned and majority owned subsidiaries (the “Company” or “REX”). All intercompany balances and transactions have been eliminated. As of January 31, 2026, the Company owns interests in three operating entities – two are consolidated and one is accounted for using the equity method of accounting. The results of One Earth are included on a delayed basis of one month lag as One Earth has a fiscal year end of December 31. The other consolidated entity has the same fiscal year end as the parent company.

Stock Split – On August 26, 2025, the Board of Directors of the Company adopted resolutions declaring a two-for-one split of the Company’s Common Stock to be effectuated in the form of a 100% stock dividend, payable on September 15, 2025 to stockholders of record at the close of business on September 8, 2025. The stock split has been retroactively reflected in the accompanying consolidated financial statements.

Fiscal Year – All references in these consolidated financial statements to a particular fiscal year are to the Company’s fiscal year ended January 31. The Company refers to its fiscal year by reference to the year immediately preceding the January 31 fiscal year end date. For example, “fiscal year 2025” means the period February 1, 2025 to January 31, 2026.

Segments – The Company has one reportable segment, ethanol and by-products. Within the ethanol and by-products segment, the Company has equity investments in three ethanol limited liability companies, two of which are majority ownership interests.

Use of Estimates – The preparation of consolidated financial statements in conformity with accounting principles generally accepted in the United States of America requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the consolidated financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates.

Cash Equivalents – Cash equivalents are principally short-term investments with original maturities of three months or less. The carrying amount of cash equivalents approximates fair value.

Concentration of Risk – The Company maintains cash and cash equivalents in accounts with financial institutions which exceed federally insured limits. The Company has not experienced any losses in such accounts. The Company does not believe there is significant credit risk related to its cash and cash equivalents.

The Company sells its products to a limited number of larger commercial buyers, which may increase the chance of loss due to non-performance by a counterparty. Ten customers in fiscal years 2025 and 2024 and nine customers in fiscal year 2023 accounted for approximately 93%, 92%, and 92% of the Company’s net sales and revenue, respectively. At January 31, 2026 and 2025, seven customers and six customers at each period end represented approximately 92% of the Company’s accounts receivable balance. The Company has not experienced any significant losses in such accounts.

Accounts Receivable — Accounts receivable are recorded at their estimated net realizable value. Accounts are considered past due if payment is not received on a timely basis in accordance with the Company’s credit terms. Accounts considered uncollectible are written off in the period they are determined to be uncollectible. As of January 31, 2026 and 2025, the Company believes that all amounts are collectible and an allowance for credit losses was not considered necessary. The balance of accounts receivables at January 31, 2024 was $23.2 million.

Inventory – Inventories are carried at the lower of cost or net realizable value. Cost for all inventories is determined using the first-in, first-out method. Net realizable value is the estimated selling prices in the ordinary course of business, less reasonable predictable costs of completion, disposal and transportation. Inventory includes direct production costs and certain overhead costs such as depreciation, property taxes and utilities related to producing ethanol and related by-product. Inventory is permanently written down for instances when cost exceeds estimated net realizable value; such write-downs are based primarily upon commodity prices as the market value of inventory is often dependent upon changes in commodity prices. The Company recorded approximately $0.1 million of inventory write-downs in cost of sales at both January 31, 2026 and January 31, 2025. Fluctuations in the write-down of inventory generally relate to the levels and composition of such inventory at a given point in time and commodity prices.

The components of inventory are as follows (amounts in thousands):

	January 31,
	2026		2025

Ethanol and other finished goods	$	5,809	$	4,923
Work in process		5,431		5,185
Grain and other raw materials		17,182		21,568

Total	$	28,422	$	31,676

Property and Equipment – Property and equipment is recorded at cost or the fair value on the date of acquisition (for property and equipment acquired in a business combination). Depreciation is computed using the straight-line method. Estimated useful lives are 15 to 40 years for buildings and improvements, and 3 to 40 years for machinery, fixtures and equipment.

The components of property and equipment are as follows (amounts in thousands):

	January 31,
	2026			2025

Land and improvements	$	42,840		$	34,112
Buildings and improvements		32,839			24,026
Machinery, equipment and fixtures		371,405			318,399
Construction in progress		98,722			94,010

Total property and equipment		545,806			470,547
Less: accumulated depreciation		(273,777	)		(259,864	)

Total property and equipment, net	$	272,029		$	210,683

Impairment of Long-Lived Assets

In accordance with ASC 360-05, the Company reviews its long-lived assets, consisting of property and equipment, equity method investments and operating lease right-of-use assets, for impairment whenever events or changes in circumstances indicate the carrying amount of the asset may not be recoverable. The Company assesses long-lived assets for impairment by first determining the forecasted, undiscounted cash flows the asset group is expected to generate. If this total is less than the carrying value of the asset, the Company will then determine the fair value of the asset group. An impairment loss would be recognized in the amount by which the carrying amount of the asset

exceeded the fair value of the asset. Significant management judgement is required to determine the fair value of long-lived assets, which includes discounted cash flows. Such estimates could be significantly affected by future changes in market conditions. The Company recorded no impairment charges in fiscal years 2025, 2024, and 2023.

Depreciation expense was approximately $15.3 million, $15.9 million, and $17.8 million in fiscal years 2025, 2024, and 2023, respectively.

Leases – The Company has lease agreements, as lessee, for railcars. All the leases are accounted for as operating leases. The lease agreements do not contain a specified implicit interest rate; therefore, the Company’s estimated incremental borrowing rate was used to determine the present value of future minimum lease payments. The lease term for all the Company’s leases includes the noncancelable period of the lease and any periods covered by renewal options that the Company is reasonably certain to exercise. Certain leases include rent escalations pre-set in the agreements, which are factored into the lease payment stream.

The Company elected the practical expedient, available pursuant to ASC 842 for lessees to include both lease and non-lease components as a single component and account for it as a lease. In general, certain maintenance costs are the responsibility of the Company under its railcar leases. These maintenance costs are a non-lease component which the Company elected to combine with rental payments and account for the total amount as operating lease expense.

The Company has one lease agreement that was classified as a finance lease for an electrical substation facility. The lease term for this lease includes the noncancelable period of the lease and any periods for which only the Company has the option to cancel but is reasonably expected to continue the lease. Based on this, the lease term was determined to be 10 years. A discount rate of 6.9% was deemed appropriate as an incremental borrowing rate for a 10-year term.

Investments – The method of accounting applied to long-term investments, whether consolidated, equity or cost, involves an evaluation of the significant terms of each investment that explicitly grant or suggest evidence of control or influence over the operations of the investee and also includes the identification of any variable interests in which the Company is the primary beneficiary. The Company accounts for investments in limited liability companies in which it may have a less than 20% ownership interest, using the equity method of accounting when the factors discussed in ASC 323 are met. The excess of the carrying value over the underlying equity in the net assets of equity method investees is allocated to specific assets and liabilities. Investments in businesses that the Company does not control but for which it has the ability to exercise significant influence over operating and financial matters are accounted for using the equity method. The Company accounts for its investment in Big River using the equity method of accounting and includes the results of Big River on a delayed basis of one month as it has a fiscal year end of December 31.

The Company periodically evaluates its investments for impairment due to declines in market value considered to be other than temporary. Such impairment evaluations include, in addition to persistent, declining market prices, general economic and company-specific evaluations. If the Company determines that a decline in market value is other than temporary, then a charge to earnings is recorded in the Consolidated Statements of Operations and a new cost basis in the investment is established.

Short-term investments, consisting of U.S. government obligations, are considered held-to-maturity, and therefore are carried at amortized historical cost.

Revenue Recognition – The Company recognizes sales of ethanol, distillers grains and distillers corn oil when obligations under the terms of the respective contracts with customers are satisfied; this occurs with the transfer of control of products, generally upon shipment from the ethanol plant or upon loading of the rail car used to transport the products.

Cost of Sales – Cost of sales includes depreciation, costs of raw materials, third-party freight charges, purchasing and receiving costs, inspection costs, other distribution expenses, warehousing costs, plant repair and maintenance costs, production labor and related payroll costs, and general facility overhead charges.

SG&A Expenses – The Company includes non-production related costs such as professional fees, selling charges, operating lease expense, and certain payroll in SG&A expenses.

Financial Instruments – Certain of the forward corn purchase and ethanol, distillers grains and distillers corn oil sale contracts are accounted for under the “normal purchases and normal sales” scope exemption of ASC 815 because these arrangements are for purchases of grain that will be delivered in quantities expected to be used and sales of ethanol, distillers grains and distillers corn oil that will be produced in quantities expected to be sold by us over a reasonable period of time in the normal course of business. During fiscal years 2025, 2024, and 2023 there were no material settlements of forward contracts that were recorded at fair value. The Company recorded an asset and liability of $0.3 million and $0.5 million, respectively, associated with contracts not accounted for under the “normal purchases and normal sales” scope exception of ASC 815 at January 31, 2026. The Company recorded an asset and liability of $1.3 million and $0.4 million, respectively, associated with contracts not accounted for under the “normal purchases and normal sales” scope exception of ASC 815 at January 31, 2025.

The Company uses derivative financial instruments (exchange-traded futures contracts and swaps) to manage a portion of the risk associated with changes in commodity prices, primarily related to corn and ethanol. The Company monitors and manages this exposure as part of its overall risk management policy. As such, the Company seeks to reduce the potentially adverse effects that the volatility of these markets may have on its operating results. The Company may take hedging positions in these commodities as one way to mitigate risk. While the Company attempts to link its hedging activities to purchase and sale activities, there are situations in which these hedging activities can themselves result in losses. The Company does not hold or issue derivative financial instruments for trading or speculative purposes. The changes in fair value of these derivative financial instruments are recognized in current period earnings as the Company does not use hedge accounting.

Stock Compensation – The Company had a stock-based compensation plan, approved by its shareholders, which reserved a total of 3,300,000 split-adjusted shares of common stock for issuance pursuant to its terms. The plan provided for the granting of shares of stock, including options to purchase shares of common stock, stock appreciation rights tied to the value of common stock, restricted stock, and restricted stock unit awards to eligible employees, non-employee directors and consultants. The Company measures share-based compensation grants at fair value on the grant date, adjusted for estimated forfeitures. The Company records noncash compensation expense related to equity and liability awards in its consolidated financial statements over the requisite service period on a straight-line basis. See Note 10 for a further discussion of restricted stock.

Other Income – As part of the Coronavirus Aid, Relief, and Economic Security Act, passed in 2020, $700 million in funds were made available to the U.S. Department of Agriculture to distribute to impacted producers of ethanol, biodiesel, and other renewable fuels under the Biofuel Producer Program. The U.S. Department of Agriculture (“USDA”) distributed funds to applicants in May 2022. Our consolidated plants received a total of approximately $1.0 million in fiscal year 2023 which was recorded within “Interest and other income, net” in the Consolidated Statements of Operations. The Company has no further reporting or other obligations related to the receipt of these funds.

Income Taxes – The Company provides for deferred tax liabilities and assets for the future tax consequences attributable to differences between the financial statement carrying amounts of existing assets and liabilities and their respective tax bases and operating loss and tax credit carryforwards. The Company provides for a valuation allowance if, based on the weight of available positive and negative evidence, it is more likely than not that some or all of the deferred tax assets will not be realized.

The Company has determined that it qualifies for clean fuel production tax credits allowable under the IRA and OBBBA. The Company elected to account for the nonrefundable, transferable tax credits under ASC 740. The credits are recognized as a tax benefit in the period in which production occurs, and the product is sold in a qualifying manner. The tax benefit recognized is determined based on the Company’s CI score to date. The Company intends on utilizing the tax credits earned in 2025 to offset taxes due and payable. The credits are recorded within income tax benefit (provision) on the consolidated statements of operations.

Comprehensive Income – The Company has no components of other comprehensive income, and therefore, comprehensive income equals net income.

New Accounting Pronouncements – In December 2023, the FASB issued ASU 2023-09, “Income Taxes (Topic 740): Improvements to Income Tax Disclosures”, to enhance the transparency and decision usefulness of income tax disclosures. This ASU was effective for all entities that are subject to Topic 740 for fiscal years beginning after December 15, 2024. The Company adopted this guidance for the fiscal-year ended January 31, 2026. See Note 16 included in the notes to the audited consolidated financial statements for more information on our income tax disclosures.

In November 2024, the FASB issued ASU 2024-03, “Income Statement - Reporting Comprehensive Income - Expense Disaggregation Disclosures (Subtopic 220-40)”, which provides clarity in assessing an entity’s performance and prospects for future cash flows by disclosure of more detailed information about the types of expenses in commonly presented expense captions. ASU 2024-03 is effective for the Company’s fiscal year-ended January 31, 2028. Early adoption is permitted. The Company is currently evaluating the impact of this ASU.

In December 2025, the FASB issued ASU 2025-10, “Accounting for Government Grants Received by Business Entities”, which establishes a unified accounting model for business entities when recognizing, measuring, and presenting government grants. The ASU categorizes grants as either related to an asset or related to income. A grant related to income is recognized in earnings in a systematic and rational manner over the periods in which the entity recognizes the related expenses. Presentation of the grant on the income statement can be either as a component of other income or as a deduction from the related expenses. The standard is effective for annual periods beginning after December 15, 2028. However, the ASU permits early adoption. The Company is still assessing the impact on its financial statements, including the presentation of its Section 45Z production tax credits.

NET SALES AND REVENUE

The Company recognizes sales of products when obligations under the terms of the respective contracts with customers are satisfied. This occurs with the transfer of control of products, generally upon shipment from the ethanol plant or upon loading of the rail car used to transport the products. Revenue is measured as the amount of consideration expected to be received in exchange for transferring goods. Sales, value added and other taxes the Company collects concurrent with revenue producing activities are excluded from net sales and revenue.

The majority of the Company’s sales have payment terms ranging from 5 to 10 days after transfer of control. The Company has determined that sales contracts do not generally include a significant financing component. The Company has not historically, and does not intend to, enter sales contracts in which payment is due from a customer prior to transferring product to the customer. Thus, the Company does not record unearned revenue.

The following table shows disaggregated revenue by product (amounts in thousands):

	Fiscal Year
		2025		2024		2023
Sales of products:

Ethanol	$	504,416	$	496,411	$	635,420
Dried distillers grains		88,156		101,432		139,173
Distillers corn oil		52,382		38,999		52,935
Modified distillers grains		5,388		4,896		5,584
Derivative financial instruments (losses) gains		(254)		424		(37)
Other		399		329		309
Total sales	$	650,487	$	642,491	$	833,384

INVESTMENTS

Equity Method Investment in Big River

The Company’s equity method investment in Big River Resources, LLC (“Big River”) is accounted for under ASC 323. The following table summarizes the investment (amounts in thousands):

	January 31,
	2026		2025

Carrying amount	$	37,759	$	35,800

Ownership percentage		10.3%		10.3%

The Company invested approximately $20.0 million in Big River which is a holding company for several entities. Big River, through its various entities (both wholly and partially owned), operates four ethanol manufacturing facilities that combined shipped approximately 432.3 million gallons of ethanol in the twelve months ended January 31, 2026. The Company recorded income of approximately $12.5 million, $9.4 million, and $13.9 million as its share of earnings from Big River during fiscal years 2025, 2024, and 2023, respectively. The Company received dividends of approximately $10.5 million, $8.5 million, and $12.0 million from Big River during fiscal years 2025, 2024, and 2023, respectively. At January 31, 2026, the carrying value of the investment in Big River was approximately $37.8 million; the amount of underlying equity in the net assets of Big River was approximately $41.0 million.

Summarized financial information for the Company’s equity method investee as of and for its fiscal year end is presented in the following tables (amounts in thousands):

	December 31,
	2025		2024

Current assets	$	346,342	$	300,492
Non current assets		181,506		181,235
Total assets	$	527,848	$	481,727

Current liabilities	$	85,296	$	89,409
Long-term liabilities		12,047		12,235
Total liabilities	$	97,343	$	101,644

Members’ capital	$	398,006	$	356,340
Noncontrolling interests		32,499		23,743
Total members’ equity	$	430,505	$	380,083

	Years Ended December 31,
	2025		2024		2023

Net sales and revenue	$	1,007,906	$	1,021,561	$	1,379,651
Gross profit	$	118,143	$	117,159	$	160,549
Depreciation expense	$	15,608	$	20,314	$	26,142
Net income	$	140,484	$	108,778	$	155,116
Net income attributable to members	$	119,448	$	93,321	$	135,012

Big River has debt agreements that limit and restrict amounts the entity can pay in the form of dividends or advances to owners. The restricted net assets of Big River at January 31, 2026 are approximately $144.1 million; the Company’s proportionate share of restricted net assets of Big River is approximately $14.9 million.

Short-term Investments

At January 31, 2026, the Company owned United States Treasury Bills (classified as short-term investments) that had an amortized cost, or carrying value, of approximately $187.0 million. The contractual maturity of these investments was less than one year. The yield to maturity rate was approximately 3.8%. Unrecognized holding losses at January 31, 2026 were approximately $52,000.

At January 31, 2025, the Company owned United States Treasury Bills (classified as short-term investments) that had an amortized cost, or carrying value, of approximately $162.8 million. The contractual maturity of these investments was less than one year. The yield to maturity rate was approximately 4.4%. Unrecognized holding losses at January 31, 2025 were approximately $19,000.

FAIR VALUE

The Company applies ASC 820 which defines fair value as the exchange price that would be received for an asset or paid to transfer a liability (an exit price) in the principal or most advantageous market for the asset or liability in an orderly transaction between market participants on the measurement date.

The Company determines the fair market values of its financial instruments based on the fair value hierarchy established by ASC 820, which requires an entity to maximize the use of observable inputs and minimize the use of unobservable inputs when measuring fair value. The standard describes three levels of inputs that may be used to measure fair values which are provided below. The Company carries certain cash equivalents, investments and derivative financial instruments at fair value.

Level 1 – Quoted prices in active markets for identical assets or liabilities. Level 1 assets and liabilities include derivative contracts that are traded in an active exchange market.

Level 2 – Observable inputs other than Level 1 prices such as quoted prices for similar assets or liabilities; quoted prices in markets that are not active; or other inputs that are observable or can be corroborated by observable market data for substantially the full term of the assets or liabilities. Level 2 assets and liabilities include derivative contracts whose value is determined using a pricing model with inputs that are observable in the market or can be derived principally or corroborated by observable market data.

Level 3 – Unobservable inputs that are supported by little or no market activity and that are significant to the fair value of the assets or liabilities. Level 3 assets and liabilities include financial instruments whose value is determined using pricing models, discounted cash flow methods, or similar techniques, as well as instruments for which the determination of fair value requires significant management judgment or estimation. Unobservable inputs are developed based on the best information available, which may include the Company’s own data.

The fair values of derivative assets and liabilities traded in the over-the-counter market are determined using quantitative models that require the use of multiple market inputs including interest rates, prices and indices to generate pricing and volatility factors, which are used to value the position. The predominance of market inputs are actively quoted and can be validated through external sources, including brokers, market transactions and third-party pricing services. Estimation risk is greater for derivative asset and liability positions that are either option-based or have longer maturity dates where observable market inputs are less readily available or are unobservable, in which case interest rate, price or index scenarios are extrapolated in order to determine the fair value. The fair values of derivative assets and liabilities include adjustments for market liquidity, counterparty credit quality, the Company’s own credit standing and other specific factors, where appropriate. The fair values of property and equipment are determined by using various models that discount future expected cash flows.

To ensure the prudent application of estimates and management judgment in determining the fair value of derivative assets and liabilities and property and equipment, various processes and controls have been adopted, which include: (i) model validation that requires a review and approval for pricing, financial statement fair value determination and risk quantification; and (ii) periodic review and substantiation of profit and loss reporting for all derivative instruments.

Financial assets and liabilities measured at fair value at January 31, 2026 on a recurring basis are summarized below (amounts in thousands):

	Level 1		Level 2		Level 3		Total Fair Value
Forward purchase contracts asset (1)	$	-	$	280	$	-	$	280
Commodity futures (2)		433		-		-		433
Total assets		433		280		-		713

Forward purchase contracts liability (3)	$	-	$	529	$	-	$	529

Financial assets and liabilities measured at fair value at January 31, 2025 on a recurring basis are summarized below (amounts in thousands):

	Level 1		Level 2		Level 3		Total Fair Value
Forward purchase contracts asset (1)	$	-	$	1,253	$	-	$	1,253
Commodity futures (2)		(1,291)		-		-		(1,291)
Total assets		(1,291)		1,253		-		(38)

Forward purchase contracts liability (3)	$	-	$	378	$	-	$	378

(1)

The forward purchase contracts asset is included in “Prepaid expenses and other” on the accompanying Consolidated Balance Sheets.

(2)

The commodity futures liability is netted with cash collateral due from broker and included in “Prepaid expenses and other” on the accompanying Consolidated Balance Sheets.

(3)

The forward purchase contracts liability is included in “Accrued expenses and other current liabilities” on the accompanying Consolidated Balance Sheets.

No other financial instruments were elected to be measured at fair value in accordance with ASC 470-20-25-21. The carrying value of all other financial assets and liabilities approximate fair value.

There were no assets measured at fair value at January 31, 2026 and 2025 on a non-recurring basis.

OTHER ASSETS

The components of other noncurrent assets are as follows (amounts in thousands):

	January 31,
	2026		2025

Deferred taxes	$	3,974	$	-
Prepaid utility equipment deposit		-		15,600
Other		989		1,121

Total	$	4,963	$	16,721

ACCRUED EXPENSES AND OTHER CURRENT LIABILITIES

The components of accrued expenses and other current liabilities are as follows (amounts in thousands):

	January 31,
	2026		2025

Accrued payroll	$	15,056	$	8,961
Accrued utility charges		3,870		3,085
Accrued capital expenditures		5,563		-
Accrued transportation related items		286		555
Forward purchase contracts		529		378
Accrued real estate taxes		1,581		1,746
Other		2,702		1,635

Total	$	29,587	$	16,360

LEASES

Operating Leases

At January 31, 2026, the Company has lease agreements, as lessee, for railcars. All the leases are accounted for as operating leases. The lease agreements do not contain a specified implicit interest rate; therefore, the Company’s estimated incremental borrowing rate was used to determine the present value of future minimum lease payments. The lease term for all the Company’s leases includes the noncancelable period of the lease and any periods covered by renewal options that the Company is reasonably certain to exercise. Certain leases include rent escalations pre-set in the agreements, which are factored into the lease payment stream.

For fiscal years 2025, 2024,and 2023, the components of lease expense, classified as SG&A expenses on the Consolidated Statement of Operations are as follows (amounts in thousands):

	Fiscal Year
		2025		2024		2023

Operating lease expense	$	8,151	$	7,209	$	6,386
Variable lease expense		174		143		301
Total lease expense	$	8,325	$	7,352	$	6,687

Total cash paid for amounts included in the measurement of lease liabilities was $7.8 million and $6.9 million for fiscal years 2025 and 2024, respectively.

The following table is a summary of future minimum rentals on such leases at January 31, 2026 (amounts in thousands):

Years Ended January 31,	Minimum Rentals

2027		$	7,706
2028			6,378
2029			3,698
2030			2,035
2031			133
Total			19,950
Less: present value discount			1,881
Operating lease liabilities		$	18,069

At January 31, 2026, the weighted average remaining lease term was 2.7 years, and the weighted average discount rate was 6.61% for the outstanding leases.

At January 31, 2025, the weighted average remaining lease term was 3.5 years, and the weighted average discount rate was 6.60% for the outstanding leases.

Finance Lease

At January 31, 2026, the Company has one lease agreement that was classified as a finance lease for an electrical substation facility. Prepayments totaling $15.6 million were made prior to fiscal year 2025 and were recorded within “Other assets” on the accompanying Consolidated Balance Sheets as of January 31, 2025. This balance was included in the finance lease right-of-use asset calculation upon lease commencement in fiscal year 2026 as a non-cash investing activity. The lease includes monthly payments of approximately $39,000 to be made over the term of the lease. The lease term for this lease includes the noncancelable period of the lease and any periods for which only the Company has the option to cancel but is reasonably expected to continue the lease. Based on this, the lease term was determined to be 10 years. Control of the facility’s output was transferred to the Company just before the end of the first quarter of 2025, with monthly lease expense commencing in the second quarter of 2025. For the year ended January 31, 2026, expense related to this lease was approximately $1.6 million, which includes approximately $171,000 in interest expense.

The weighted average remaining lease term for the finance lease is 9.3 years as of January 31, 2026. A discount rate of 6.9% was deemed appropriate as an incremental borrowing rate for a 10-year term.

The following table is a summary of future minimum rentals on the lease at January 31, 2026 (amounts in thousands):

Years Ended January 31,	Minimum Rentals

2027		$	469
2028			469
2029			469
2030			469
2031			469
Thereafter			1,994
Total			4,339
Less: present value discount			1,138
Finance lease liabilities		$	3,201

COMMON STOCK

On August 26, 2025, the Board of Directors of the Company adopted resolutions declaring a two-for-one split of the Company’s Common Stock to be effectuated in the form of a 100% stock dividend, payable on September 15, 2025 to stockholders of record at the close of business on September 8, 2025. The stock split has been retroactively reflected in the accompanying consolidated financial statements.

During fiscal years 2025 and 2024 the Company purchased approximately 1,651,000 shares and 745,000 shares of its common stock for approximately $32.9 million and $15.5 million, respectively. The Company did not purchase any shares of its common stock during fiscal year 2023. At January 31, 2026, the Company had prior authorization by its Board of Directors to purchase, in open market transactions, approximately an additional 2,357,000 shares of its common stock.

Information regarding the Company’s common stock is as follows (amounts in thousands):

	January 31,
	2026		2025

Authorized shares		45,000		45,000
Issued shares		32,938		34,389
Outstanding shares		32,938		34,389

DERIVATIVE FINANCIAL INSTRUMENTS

The Company is exposed to various market risks, including changes in commodity prices (raw materials and finished goods). To manage risks associated with the volatility of these natural business exposures, the Company enters into commodity agreements (exchange-traded futures contracts and swaps) and forward purchase (corn) and sale (ethanol, distillers grains and distillers corn oil) contracts. The Company does not purchase or sell derivative financial instruments for trading or speculative purposes. The Company does not purchase or sell derivative financial instruments for which a lack of marketplace quotations would require the use of fair value estimation techniques. The changes in fair value of these derivative financial instruments are recognized in current period earnings as the Company does not use hedge accounting.

The following table provides information about the fair values of the Company’s derivative financial instruments and the line items on the Consolidated Balance Sheets in which the fair values are reflected (amounts in thousands):

		Asset Derivatives						Liability Derivatives
		Fair Value at January 31,						Fair Value at January 31,
	2026			2025			2026			2025

Forward purchase contracts (1)		$	280		$	1,253		$	529		$	378

Cash collateral balance (2)		$	180		$	2,523			-			-
Commodity futures (3)			433			(1,291)			-			-
Net position with broker		$	613		$	1,232			-			-

Total		$	893		$	2,485		$	529		$	378

(1)

Forward purchase contracts assets are included in “Prepaid expenses and other” on the accompanying Consolidated Balance Sheets. These contracts are for purchases of approximately 8.8 million and 16.8 million bushels of corn at January 31, 2026 and 2025, respectively.

Forward purchase contracts liabilities are included in “Accrued expenses and other current liabilities” on the accompanying Consolidated Balance Sheets. These contracts are for purchases of approximately 9.6 million and 7.6 million bushels of corn at January 31, 2026 and 2025, respectively.

(2)

As of January 31, 2026, and 2025, all of the derivative financial instruments held by the Company were subject to enforceable master netting arrangements. The Company’s accounting policy is to offset position amounts owed or owing with the same counterparty. Depending on the amount of unrealized gains and losses on derivative contracts held by the Company, the counterparty may require collateral to secure the Company’s derivative contract positions. As of January 31, 2026 and 2025, the Company was required to maintain collateral with the counterparty in the amount of approximately $180,000 and $2,523,000, respectively, recorded within “Prepaid expenses and other” on the accompanying Consolidated Balance Sheets.

(3)

Commodity futures assets and liabilities are included in “Prepaid expenses and other” on the accompanying Consolidated Balance Sheets. These contracts included short/sell positions and long/buy positions for approximately 2.4 million and 1.8 million bushels of corn, respectively at January 31, 2026. These contracts also included short/sell positions for approximately 3.6 million gallons of ethanol at January 31, 2026. These contracts included short/sell positions and long/buy positions for approximately 6.3 million and 575,000 bushels of corn, respectively at January 31, 2025. These contracts also included short/sell positions for approximately 4.2 million gallons of ethanol at January 31, 2025.

See Note 4 which contains fair value information related to derivative financial instruments.

The following table provides information about (losses) gains recognized in income on the Company’s derivative financial instruments and the line items on the accompanying Consolidated Statements of Operations in which the fair values are reflected for the years ended January 31, 2026, 2025, and 2024 (amounts in thousands):

	Year Ended January 31,
	2026		2025		2024

Net sales	$	(254)	$	424	$	(37)

Cost of sales	$	5,375	$	(2,739)	$	15,023

10.

EMPLOYEE BENEFITS

Until its expiration on June 1, 2025 the Company maintained the REX American Resources Corporation 2015 Incentive Plan, approved by its shareholders, which reserved a total of 3,300,000 split-adjusted shares of common stock for issuance pursuant to its terms. The plan provided for the granting of shares of stock, including options to purchase shares of common stock, stock appreciation rights tied to the value of common stock, restricted stock, and restricted stock unit awards to eligible employees, non-employee directors and consultants. Until 2022, the Company had only granted restricted stock awards. In May 2022, the Company issued restricted stock units to certain officers of the Company which vested based on the Company’s TSR compared to the TSRs of companies that comprise the Russell 2000 Index over a three-year performance period (see below). The Company measures share-based compensation grants at fair value on the grant date, adjusted for estimated forfeitures. The Company records non-cash compensation expense related to equity awards in its consolidated financial statements over the requisite service period on a straight-line basis. At the time of its expiration, 1,065,809 shares (pre-2025 split) remained available for issuance under the Plan.

Restricted Stock Awards

As a component of their compensation, restricted stock has been granted to directors and certain employees at the closing market price of REX common stock on the date of the grant. In addition, one-quarter of executives’ incentive compensation is payable by an award of restricted stock based on the then market price of REX common stock on the date of grant. The Company’s board of directors has determined that the grant date will be June 15^th, or the next business day, for all grants of restricted stock.

Based on retirement eligibility provisions, a portion of restricted stock grants are expensed at grant date, based on grant date fair value, thus considered vested for accounting purposes. At January 31, 2026, 20,964 shares were unvested for accounting purposes and unrecognized compensation cost related to these nonvested restricted stock awards was approximately $245,000, to be recognized over a weighted average vesting term of 1.2 years.

The following table summarizes legally non-vested restricted stock award activity for fiscal years 2025, 2024, and 2023:

	2025
		Non-Vested Shares		Weighted Average Grant Date Fair Value (000’s)	Weighted Average Remaining Vesting Term (in years)
Non-Vested at January 31, 2025		324,784	$	6,190	2
Granted		-		-
Forfeited		-		-
Vested		164,420		2,946

Non-Vested at January 31, 2026		160,364	$	3,244	1

	2024
	Non-Vested Shares		Weighted Average Grant Date Fair Value (000’s)		Weighted Average Remaining Vesting Term (in years)
Non-Vested at January 31, 2024		325,710	$	5,369		2
Granted		126,814		2,894
Forfeited		-		-
Vested		127,740		2,073

Non-Vested at January 31, 2025		324,784	$	6,190		2

	2023
	Non-Vested Shares		Weighted Average Grant Date Fair Value (000’s)		Weighted Average Remaining Vesting Term (in years)
Non-Vested at January 31, 2023		162,528	$	2,320		2
Granted		227,452		3,945
Forfeited		-		-
Vested		64,270		896

Non-Vested at January 31, 2024		325,710	$	5,369		2

Restricted Stock Units

In May 2022, the Company issued a total of 135,000 RSUs to certain officers with a performance period that ended on December 31, 2024. The number of RSUs eligible to vest ranged from zero percent to two-hundred percent and was determined based on how the Company’s TSR compared to the TSR of companies that comprise the Russell 2000 Index during the performance period. The calculated payout of the RSUs that vested was 148%, or 199,800 shares of REX common stock, and the shares were issued on February 26, 2025.

The Company did not recognize any compensation cost related to RSUs for the year ended January 31, 2026. For the years ended January 31, 2025 and 2024, the Company recognized compensation cost of approximately $0.9 million and $1.1 million, respectively, related to RSUs. There was no unrecognized compensation cost related to nonvested RSUs at January 31, 2026 and 2025, respectively.

At January 31, 2024, we calculated the diluted weighted average shares as follows (amounts in thousands):

Weighted average shares - basic	34,964
Dilutive effect of RSUs	187
Weighted average shares - diluted	35,151


11.	COMMITMENTS

At January 31, 2026, One Earth and NuGen had combined forward purchase contracts for approximately 18.4 million bushels of corn, the principal raw material for their ethanol plants and they had combined forward purchase contracts for approximately 1.7 million MmBtu of natural gas.

At January 31, 2026, One Earth and NuGen had combined sales commitments for approximately 54.8 million gallons of ethanol, 107,000 tons of distillers grains and 17.0 million pounds of distillers corn oil.

At January 31, 2026, One Earth and NuGen had signed contracts in place for capital projects of approximately $16.2 million.

One Earth has entered into a 10-year agreement in 2009 with an unrelated party for the use of a portion of that party’s natural gas pipeline. A new 15-year agreement, with monthly payments of $29,250 was effective February 1, 2019. One Earth paid approximately $351,000 in fiscal years 2025, 2024, and 2023 pursuant to the agreement.

One Earth and NuGen each have a contract with an unrelated party (“Distillers Grains Marketers”) for distillers grains marketing services. Under the terms of the contracts, the Distillers Grains Marketers will purchase all of One Earth’s and NuGen’s distillers grains production during the term of the contracts. The contracts call for One

Earth and NuGen to pay a fee per ton of distillers grains sold for the Distillers Grains Marketers’ services. The terms of the agreements are for one year and renew automatically for additional one-year terms, unless either party sends notice to the other party of its intent to terminate the agreement at least 90 days prior to the expiration of the then current term of the agreement. One Earth and NuGen combined incurred fees of approximately $1,062,000 $1,110,000, and $1,199,000 in fiscal years 2025, 2024, and 2023, respectively, for these marketing services.

12.

INCOME TAXES

The provision for income taxes for fiscal years 2025, 2024, and 2023 consists of the following (amounts in thousands):

	2025			2024		2023

Federal:
Current	$	(4,340	)	$	4,232	$	4,580
Deferred		(5,254	)		13,522		14,102

Total		(9,594	)		17,754		18,682

State and Local:
Current		1,310			2,947		3,377
Deferred		1,782			685		501

Total		3,092			3,632		3,878

(Benefit) provision for income taxes	$	(6,502	)	$	21,386	$	22,560

The tax effects of significant temporary differences representing deferred tax assets and liabilities are as follows (amounts in thousands):

	January 31,
	2026			2025

Assets:
General business credit carryforward	$	24,701		$	4,151
Accrued liabilities		569			628
State net operating loss carryforward		81			167
Other items		387			311
Valuation allowance		(64	)		(132	)

Total		25,674			5,125
Liabilities:
Basis in pass through entities, including depreciation		(25,765	)		(7,470	)
Other		-			(1,217	)

Total		(25,765	)		(8,687	)
Net deferred tax liability	$	(91	)	$	(3,562	)

The net deferred tax liability is reported on the accompanying Consolidated Balance Sheets based on net position by tax jurisdiction, within federal positions of approximately $4.0 million recorded as assets on the Consolidated Balance Sheets within “Other assets” and state positions of $4.1 million recorded as liabilities on the accompanying Consolidated Balance Sheets at January 31, 2026. At January 31, 2025, both federal positions and state positions were recorded as net liabilities with “Deferred taxes” on the Consolidated Balance Sheets.

On July 4, 2025, the OBBBA was signed into law. The OBBBA contains various tax reform provisions affecting businesses, such as the extension of bonus depreciation for assets placed in service after January 19, 2025 and immediate expensing of domestic research and development costs, to result in current deductions that will lower cash paid for income taxes for 2025. The OBBBA made changes to the 45Z and 45Q tax credits that the Company intends to take advantage of which materially impact our effective tax rate. The Section 45Z clean fuel production credit is a general business credit that is allowed with respect to clean transportation fuel produced domestically after December 31, 2024, and before December 31, 2029. This credit, which was part of the IRA, and subsequently extended by the OBBBA, incentivizes the production of clean fuels at our plants that reduce GHG emissions below a CI score of 50. The tax credit utilizes a sliding scale where credits can be earned incrementally between $0.02 and $0.20, or $0.10 and $1.00 if prevailing wage and apprenticeship requirements are met, per gallon of non-SAF fuels based on an ethanol plant’s GHG reduction below a 50 CI score threshold, with the first two or ten cents earned upon achieving a CI score below 47.5. The company expects that it is more-likely-than-not that prevailing wage and apprenticeship requirements will be met for 2025 for its consolidated ethanol plants and has calculated the credit at the highest credit rate based on its CI score for 2025, after the purchase of EACs.

The Company has a general business credit carryforward, net of the impact of uncertain tax positions, of approximately $24.7 million and $4.2 million at January 31, 2026 and 2025, respectively. The credits at January 31, 2025 were fully utilized as part of the effective settlement of the IRS audit that is in process of being finalized. The Company earned 45Z clean fuel production credits in 2025 that make up the $24.7 million of credits to be carried forward at January 31, 2026. The Company can carry these credits forward for up to twenty-two years. The carryforward periods expire in fiscal year 2047.

The Company has a valuation allowance of approximately $64,000 and $132,000 at January 31, 2026 and 2025, respectively, related to state net operating loss carryforwards. The Company decreased the valuation allowance by $68,000 in fiscal year 2025. These adjustments to the valuation allowance are a result of estimates of realizing certain future state tax benefits.

The Company assessed all available positive and negative evidence to determine whether it expects sufficient future taxable income will be generated to allow for the realization of existing federal deferred tax assets. There is sufficient objectively verifiable income for management to conclude that it is more likely than not that the Company will utilize available federal deferred tax assets prior to their expiration.

During fiscal year 2025, the Company recognized an income tax benefit for federal 45Z clean fuel production credits of approximately $28.1 million. The credits can be used to reduce future income tax liabilities for up to 22 years.

The Company paid income taxes in fiscal years 2025, 2024, 2023 of the following (amounts in thousands):

	2025		2024		2023
Federal	$	2,000	$	4,700	$	7,000
State		4,086		3,195		5,730
Total	$	6,086	$	7,895	$	12,730

The Company received no refunds in fiscal years 2025, 2024, and 2023.

Income taxes paid (net of refunds) exceeded 5 percent of total income taxes paid (net of refunds) in the following state jurisdictions in fiscal years 2025, 2024 and 2023 (amounts in thousands):

	2025		2024		2023
State
Illinois	$	4,021	$	3,052	$	5,450

Reconciliations of the federal statutory tax and the Company’s income tax (benefit) provision for fiscal years 2025, 2024, and 2023 are as follows (amounts in thousands):

	2025						2024						2023
	Amount			%			Amount			%			Amount			%
Tax at U.S. statutory rate	$	18,600			21.0	%	$	19,503			21.0	%	$	20,682			21.0	%
State and local taxes, net of federal tax benefit		2,988			3.4			3,008			3.2			3,299			3.3
Tax credits
45Z credits		(28,142	)		(31.8	)		-			-			-			-
Other credits		(193	)		(0.2	)		(182	)		(0.2	)		(204	)		(0.2	)
Nontaxable and nondeductible items
Nondeductible compensation		2,432			2.7			2,062			2.2			2,150			2.2
Nontaxable 45Z revenue, passed through		(824	)		(0.9	)		-			-			-			-
Changes in uncertain tax positions		1,181			1.3			11			-			(98	)		(0.1	)
Noncontrolling interest		(2,955	)		(3.3	)		(3,228	)		(3.5	)		(3,650	)		(3.7	)
Other adjustments		411			0.5			212			0.3			381			0.4

Total	$	(6,502	)		(7.3%	)	$	21,386			23.0%		$	22,560			22.9%

The Company files a U.S. federal income tax return and income tax returns in various states. In general, the Company is no longer subject to U.S. federal, state or local income tax examinations by tax authorities for fiscal years ended January 31, 2014 and prior. The Company is currently finalizing, as a settlement agreement has been reached, a federal income tax examination for the years ended January 31, 2015 through January 31, 2022 related to tax credits claimed on returns during those years.

The Company applies the provisions of ASC 740-10-25-5 for uncertain tax positions. Tax positions held at January 31, 2025 related to the research and experimentation credits that are under IRS audit have been considered effectively settled as of January 31, 2026. The Company has reached a settlement with the IRS and is in process of finalizing the audit. As of January 31, 2026, total unrecognized tax benefits were approximately $259,000, and accrued penalties and interest were approximately $124,000. If the Company were to prevail on all unrecognized tax benefits recorded, the provision for income taxes would be reduced by approximately $178,000. In addition, the impact of penalties and interest would also benefit the effective tax rate. Interest and penalties associated with unrecognized tax benefits are recorded within income tax expense.

On a quarterly and annual basis, the Company accrues for the effects of open uncertain tax positions and the related potential penalties and interest. It is reasonably possible that the amount of the unrecognized tax benefit with respect to certain unrecognized tax positions will increase or decrease during the next 12 months; however, the Company does not expect the change to have a material effect on results of operations or financial position. The Company accounts for uncertainty in income taxes by determining whether it is more likely than not the position will be sustained on audit, including resolution of any related tax audits.

A reconciliation of the beginning and ending amount of unrecognized tax benefits, including interest and penalties, is as follows (amounts in thousands):

	Fiscal Year
	2025			2024

Unrecognized tax benefits, beginning of year	$	18,978		$	18,965
Changes for tax positions for prior years		(18,706	)		19
Changes for tax positions for current year		111			(6	)

Unrecognized tax benefits, end of year	$	383		$	18,978

At January 31, 2026 and 2025, the total unrecognized tax benefits were included within the following lines on the accompanying Consolidated Balance Sheets (amounts in thousands):

	January 31,
	2026			2025

Refundable income taxes	$	(88	)	$	2,002
Deferred taxes		-			12,037
Long-term taxes payable		-			4,334
Other long-term liabilities		471			605

Unrecognized tax benefits, end of year	$	383		$	18,978


13.	CONTINGENCIES

The Company is involved in various legal actions arising in the normal course of business. After taking into consideration legal counsels’ evaluation of such actions, management is of the opinion that their outcome will not have a material effect on the Company’s consolidated financial statements. There were no liabilities recorded at January 31, 2026 as the Company did not believe that there was a probable and reasonably estimable loss associated with any legal contingencies.

14.

RELATED PARTIES

During fiscal years 2025, 2024, and 2023, One Earth and NuGen, combined, purchased approximately $86.4 million, $99.2 million, and $117.0 million, respectively, of corn and other supplies from minority equity investors. The Company had amounts payable to related parties of approximately $1.2 million and $1.4 million at January 31, 2026 and 2025, respectively.

During fiscal year 2024, $1.5 million was paid to landowners who are equity investors of One Earth Energy, for land easements related to the carbon sequestration project.

15.

SEGMENT REPORTING

The Company has one reportable segment, ethanol and by-products. Within the ethanol and by-products segment, the Company has equity investments in three ethanol limited liability companies, two of which are majority ownership interests and are consolidated in the financial statements presented. Prior period amounts have been reclassified to conform to current segment reporting.

The Company’s chief operating decision maker is the Executive Committee that includes the Executive Chairman of the Board and The Chief Executive Officer. The chief operating decision maker uses net income generated from operating segments in determining the allocation of resources and making assessment of Company performance.

In applying the criteria set forth in ASC 280 the Company determined that based on the nature of the products and production process and the expected financial results, the Company’s operations at its ethanol plants, each of which is reviewed in the same manner by the CODM, are aggregated into one reporting segment. Aggregation into one reporting segment is appropriate based upon the similarity of economic characteristics of the operating segments, including the markets for identical revenue sources and the primary input, corn. The plants in all locations operate in a similar manner to produce ethanol and by-products. The types of customers and how the products are distributed to the customers are similar across each operating entity, consisting of a combination of rail and truck shipments. Finally, the regulatory environment is largely impacted by guidance from the federal level, impacting each operating segment the same. The measure of segment assets is reported on the balance sheet as total consolidated assets.

The following tables set forth certain financial data for the Company’s reportable segment for the years ended January 31, 2026, 2025 and 2024 (amounts in thousands):

	Fiscal Year
	2025			2024			2023
Net sales and revenue
Ethanol and by-products	$	1,658,393		$	1,664,052		$	2,213,035
Reconciling Item: Equity method ethanol investment		(1,007,906	)		(1,021,561	)		(1,379,651	)
Total consolidated net sales and revenue	$	650,487		$	642,491		$	833,384

Cost of sales
Ethanol and by-products:
Cost of corn	$	1,057,816		$	1,094,364		$	1,542,265
Other cost of sales (1)		388,728			361,052			412,003
Reconciling Item: Equity method ethanol investment		(889,763	)		(904,402	)		(1,219,102	)
Total cost of sales	$	556,781		$	551,014		$	735,166

Gross profit
Ethanol and by-products	$	211,849		$	208,636		$	258,767
Reconciling Item: Equity method ethanol investment		(118,143	)		(117,159	)		(160,549	)
Total consolidated gross profit	$	93,706		$	91,477		$	98,218

Depreciation and amortization expense
Ethanol and by-products	$	46,374		$	49,071		$	56,207
Reconciling Item: Equity method ethanol investment		(23,212	)		(27,356	)		(33,168	)
Total consolidated depreciation and amortization expense	$	23,162		$	21,715		$	23,039

Income before taxes
Ethanol and by-products	$	229,056		$	201,650		$	253,600
Reconciling Item: Equity method ethanol investment		(140,484	)		(108,778	)		(155,116	)
Total consolidated income before income taxes		88,572			92,872			98,484
Provision for income taxes		6,502			(21,386	)		(22,560	)
Total consolidated net income	$	95,074		$	71,486		$	75,924

(1)

Expenses within “Other cost of sales” consists primarily of depreciation, other raw materials such as denaturant and chemicals, utilities, repair and maintenance and production labor.

* * * * * *

Report of Independent Registered Public Accounting Firm

To the Shareholders and the Board of Directors of REX American Resources Corporation

Opinion on the Financial Statements

We have audited the accompanying consolidated balance sheets of REX American Resources Corporation and its subsidiaries (the Company) as of January 31, 2026 and 2025, the related consolidated statements of operations, shareholders’ equity and cash flows for each of the three years in the period ended January 31, 2026, and the related notes to the consolidated financial statements and schedules (collectively, the financial statements). In our opinion, the financial statements present fairly, in all material respects, the financial position of the Company as of January 31, 2026 and 2025, and the results of its operations and its cash flows for each of the three years in the period ended January 31, 2026, in conformity with accounting principles generally accepted in the United States of America.

We have also audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States) (PCAOB), the Company’s internal control over financial reporting as of January 31, 2026, based on criteria established in Internal Control — Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission in 2013, and our report dated March 30, 2026 expressed an unqualified opinion on the effectiveness of the Company’s internal control over financial reporting.

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 audits. We are a public accounting firm registered with the 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 audits in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement, whether due to error or fraud. Our audits 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 audits provide a reasonable basis for our opinion.

Critical Audit Matters

The critical audit matter communicated below is a matter arising from the current period audit of the financial statements that was communicated or required to be communicated to the audit committee and that: (1) relates to accounts or disclosures that are material to the financial statements and (2) involved our especially challenging, subjective or complex judgments. The communication of critical audit matters does not alter in any way our opinion on the financial statements, taken as a whole, and we are not, by communicating the critical audit matter below, providing separate opinions on the critical audit matter or on the accounts or disclosures to which it relates.

45Z Tax Credit Recognition

As described in Note 1 and Note 12 to the financial statements, the Company has determined that it qualifies for clean fuel production tax credits allowable under the Inflation Reduction Act (IRA) and One Big Beautiful Bill Act (OBBBA). The Company elected to account for the nonrefundable, transferable tax credits under ASC 740. The credits are recognized as a tax benefit in the period in which production occurs, and the product is sold in a qualifying manner. The tax benefit recognized is determined based on the company’s carbon intensity (CI) score to date. In accordance with ASC 740, the tax incentives are recognized when it is more-likely-than-not the Company will comply with the provisions of the incentive and that the incentive will be received. The Company recognized $28,100,000, as 45Z Tax Credits within the balance sheet (deferred tax asset) and statement of operations (income tax benefit) as of and for the year ended January 31, 2026.

We identified the accounting for the 45Z tax credits as a critical audit matter because of the significant judgments management makes when determining how to account for the 45Z tax credits given the significant unusual nature of the credits, as well as when determining eligibility for the tax credits. The 45Z tax credit recognition required a high degree of auditor judgment when performing audit procedures to evaluate whether management appropriately determined eligibility and accounted for the tax credits.

Our audit procedures related to the accounting for the 45Z tax credits included the following, among others:

●	We obtained an understanding of management’s process and internal controls over the determination of eligibility, valuation of, and accounting for tax credits and tested the operating effectiveness of the controls.

●	We obtained evidence of the facilities’ approved registrations as clean transportation fuel producers.

●	We compared production and sales volumes to internal production records and sales invoices, which were subjected to our revenue testing.

●	We agreed the emissions rates to certifications provided by a qualified third-party verifier or, when certifications were not available, agreed inputs into the 45ZCF-GREET model to internal records and third-party invoices and validated mathematical accuracy.

/s/ RSM US LLP

We have served as the Company’s auditor since 2023.

Des Moines, Iowa
March 30, 2026

REX AMERICAN RESOURCES CORPORATION AND SUBSIDIARIES

Schedule II - VALUATION AND QUALIFYING ACCOUNTS

FOR THE YEARS ENDED JANUARY 31, 2026, 2025, AND 2024

(Amounts in thousands)

	Balance Beginning of Year		Additions Charged to Cost and Expenses		Deductions Charges for Which Reserves Were Created		Balance End of Year

2026:
Deferred tax valuation allowance	$	132	$	-	$	68	$	64

2025:
Deferred tax valuation allowance	$	160	$	-	$	28	$	132

2024:
Deferred tax valuation allowance	$	192	$	-	$	32	$	160

Item 9.	Changes in and Disagreements with Accountants on Accounting and Financial Disclosure

	None.

Item 9A.	Controls and Procedures

Evaluation of Disclosure Controls and Procedures

Our management evaluated, with the participation of our Chief Executive Officer and Chief Financial Officer, the effectiveness of our disclosure controls and procedures (as defined in Rules 13a–15(e) and 15d–15(e) under the Securities Exchange Act of 1934) as of the end of the period covered by this report. Based on that evaluation, our Chief Executive Officer and Chief Financial Officer concluded that our disclosure controls and procedures are effective at the reasonable assurance level to ensure that information required to be disclosed by us in the reports that we file or submit under the Securities Exchange Act of 1934 is recorded, processed, summarized and reported within the time periods specified in the Securities and Exchange Commission’s rules and forms. Our officers concluded that our disclosure controls and procedures are also effective at the reasonable assurance level to ensure that information required to be disclosed in the reports that we file or submit under the Exchange Act is accumulated and communicated to our management, including our Chief Executive Officer and Chief Financial Officer, to allow timely decisions regarding required disclosure.

Material Changes to Internal Control Over Financial Reporting

There were no changes in our internal control over financial reporting that occurred during our last fiscal quarter that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

Management’s Annual Report on Internal Control Over Financial Reporting

Our management is responsible for establishing and maintaining adequate internal control over financial reporting, as defined in Exchange Act Rule 13a-15(f). Our internal control over financial reporting is designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements in accordance with accounting principles generally accepted in the United States of America.

All internal control systems, no matter how well designed, have inherent limitations. Therefore, even those systems deemed to be effective can provide only reasonable assurance with respect to financial statement preparation and presentation.

Under the supervision and with the participation of our senior management, including our Chief Executive Officer and Chief Financial Officer, we assessed the effectiveness of our internal control over financial reporting as of January 31, 2026 based on the Internal Control-Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission (“COSO”). Based upon this assessment, our management concluded that our internal control over financial reporting was effective as of January 31, 2026 based on those criteria.

The effectiveness of our internal control over financial reporting as of January 31, 2026 has been audited by RSM US LLP, an independent registered public accounting firm, as stated in their report which is included herein.

/s/ ZAFAR A. RIZVI Zafar A. Rizvi	Chief Executive Officer and President (principal executive officer)	March 30, 2026

/s/ DOUGLAS L. BRUGGEMAN	Vice President-Finance, Chief Financial Officer and Treasurer
Douglas L. Bruggeman	(principal financial and accounting officer)	March 30, 2026

Report of Independent Registered Public Accounting Firm

To the Shareholders and the Board of Directors of REX American Resources Corporation

Opinion on the Internal Control Over Financial Reporting

We have audited REX American Resources Corporation and its subsidiaries (the Company) internal control over financial reporting as of January 31, 2026, based on criteria established in Internal Control—Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission in 2013. In our opinion, the Company maintained, in all material respects, effective internal control over financial reporting as of January 31, 2026, based on criteria established in Internal Control—Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission in 2013.

We have also audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States) (PCAOB), the consolidated financial statements of the Company and our report dated March 30, 2026, expressed an unqualified opinion.

Basis for Opinion

The Company’s management is responsible for maintaining effective internal control over financial reporting and for its assessment of the effectiveness of internal control over financial reporting in the accompanying Management’s Annual Report on Internal Control over Financial Reporting. Our responsibility is to express an opinion on the Company’s internal control over financial reporting based on our audit. We are a public accounting firm registered with the 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. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether effective internal control over financial reporting was maintained in all material respects. Our audit included obtaining an understanding of internal control over financial reporting, assessing the risk that a material weakness exists, and testing and evaluating the design and operating effectiveness of internal control based on the assessed risk. Our audit also included performing such other procedures as we considered necessary in the circumstances. We believe that our audit provides a reasonable basis for our opinion.

Definition and Limitations of Internal Control Over Financial Reporting

A company’s internal control over financial reporting is a process designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles. A company’s internal control over financial reporting includes those policies and procedures that: (1) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of the assets of the company; (2) provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with generally accepted accounting principles, and that receipts and expenditures of the company are being made only in accordance with authorizations of management and directors of the company; and (3) provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use or disposition of the company’s assets that could have a material effect on the financial statements.

Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Also, projections of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.

/s/ RSM US LLP

Des Moines, Iowa

March 30, 2026

Item 9B.

Other Information

None.

Item 9C.

Disclosure Regarding Foreign Jurisdictions that Prevent Inspections

Not applicable.

PART III

Item 10.

Directors, Executive Officers and Corporate Governance

The information required by this Item 10 is incorporated herein by reference to the Proxy Statement for our Annual Meeting of Shareholders on May 28, 2026, except for certain information concerning our executive officers which is set forth in Part I of this report.

Item 11.

Executive Compensation

The information required by this Item 11 is set forth in the Proxy Statement for our Annual Meeting of Shareholders on May 28, 2026 and is incorporated herein by reference.

Item 12.

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

The information required by this Item 12 is set forth in the Proxy Statement for our Annual Meeting of Shareholders on May 28, 2026 and is incorporated herein by reference.

Item 13.

Certain Relationships and Related Transactions and Director Independence

The information required by this Item 13 is set forth in the Proxy Statement for our Annual Meeting of Shareholders on May 28, 2026 and is incorporated herein by reference.

Item 14.

Principal Accountant Fees and Services

The information required by this Item 14 is set forth in the Proxy Statement for our Annual Meeting of Shareholders on May 28, 2026 and is incorporated herein by reference.

PART IV

Item 15.

Exhibits and Financial Statement Schedules

(a)(1) Financial Statements

The following consolidated financial statements of REX American Resources Corporation and subsidiaries are filed as a part of this report at Item 8 hereof.

Consolidated Balance Sheets as of January 31, 2026 and 2025

Consolidated Statements of Operations for the years ended January 31, 2026, 2025, and 2024

Consolidated Statements of Cash Flows for the years ended January 31, 2026, 2025, and 2024

Consolidated Statements of Shareholders’ Equity for the years ended January 31, 2026, 2025, and 2024

Notes to Consolidated Financial Statements

Reports of Independent Registered Public Accounting Firm-RSM US LLP (PCAOB ID No. 49)

(a)(2)(i) Financial Statement Schedules

The following financial statement schedules are filed as a part of this report at Item 8 hereof.

Schedule II -Valuation and Qualifying Accounts

All other schedules are omitted because they are not applicable or not required, or because the required information is included in the consolidated financial statements or notes thereto.

(a)(3) Exhibits

	EXHIBIT INDEX

(3)(i)	Articles of Incorporation:

	3(i)	Certificate of Incorporation, as amended (incorporated by reference to Exhibit 3(a) to Form 10-Q for quarter ended July 31, 2010, File No. 001-09097)

(3)(ii)	Bylaws:

	3(ii)	By-Laws, as amended (incorporated by reference to Exhibit 3(ii) to Form 8-K filed August 7, 2024, File No. 001-09097)

(4)	Instruments defining the rights of securities holders, including indentures:

	4(a)	Description of Securities Registered Under Section 12 of the Exchange Act (incorporated by reference to Exhibit 4(a) to Form 10-K filed April 1, 2020, File No. 001-09097)

(10)	Material contracts:

	10(a)*	Employment Agreement dated May 24, 2022 between Rex Radio and Television, Inc. (a subsidiary of the Company) and Zafar A. Rizvi (incorporated by reference to Exhibit 10.1 to Form 8-K filed May 27, 2022, File No. 001-09097)

	10(b)*	Employment Agreement dated May 24, 2022 between Rex Radio and Television, Inc. (a subsidiary of the Company) and Douglas L. Bruggeman (incorporated by reference to Exhibit 10.2 to Form 8-K filed May 27, 2022, File No. 001-09097)

	10(c)*	Employment Agreement dated May 24, 2022 between Rex Radio and Television, Inc. (a subsidiary of the Company) and Stuart A. Rose (incorporated by reference to Exhibit 10.3 to Form 8-K filed May 27, 2022, File No. 001-09097)

	10(d)*	2015 Incentive Plan (incorporated by reference to Exhibit 10(d) to Form 8-K filed June 8, 2015, File No. 001-09097)

	10(e)*	Form of Restricted Stock Award Agreement under the REX American Resources 2015 Incentive Plan (incorporated by reference to Exhibit 10.1 to Form 8-K filed June 22, 2022, File No. 001-09097)

	10(f)	Consulting Services Agreement, effective as of January 1, 2026, between One Earth Sequestration LLC and Mercury Public Affairs LLC

(19)	Insider trading policies and procedures:

	19	REX American Resources Corporation Revised Insider Trading Policy (incorporated by reference to Exhibit 4(a) to Form 10-K filed March 28, 2025, File No. 001-09097)

(21)	Subsidiaries of the registrant:

	21	Subsidiaries of registrant

(23)	Consents of experts and counsel:

	23	Consent of RSM US LLP, Independent Registered Public Accounting Firm

(31)	Rule 13a-14(a)/15d-14(a) Certifications:

	31	Certifications

(32)	Section 1350 Certifications:

	32	Certifications

(97)	Policy relating to erroneously awarded compensation:

	97	REX American Resources Corporation Compensation Recovery Policy (incorporated by reference to Exhibit 97.1 to Form 10-K filed March 29, 2024, File No. 001-09097)

(101)	Interactive Data File:

	101	The following information from REX American Resources Corporation Annual Report on Form 10-K for the fiscal year ended January 31, 2026, formatted in iXBRL: (i) Consolidated Balance Sheets, (ii) Consolidated Statements of Operations, (iii) Consolidated Statements of Shareholders’ Equity, (iv) Consolidated Statements of Cash Flows and (v) Notes to Consolidated Financial Statements.

	104	The cover page from REX American Resources Corporation on Form 10-K for the year ended January 31, 2026

		Copies of the Exhibits not filed herewith may be obtained by writing to Edward M. Kress, Secretary, REX American Resources Corporation, 7720 Paragon Road, Dayton, Ohio 45459

Those exhibits marked with an asterisk (*) above are management contracts or compensatory plans or arrangements for directors or executive officers of the registrant.

Item 16.

Form 10-K Summary

None.

SIGNATURES

Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.

	REX AMERICAN RESOURCES CORPORATION

	By: /s/ ZAFAR A. RIZVI Zafar A. Rizvi Chief Executive Officer and President

Date: March 30, 2026

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

Signature	Capacity	Date

/s/ STUART A. ROSE Stuart A. Rose	Executive Chairman of the Board	March 30, 2026

/s/ ZAFAR A. RIZVI Zafar A. Rizvi	Chief Executive Officer, President and Director (principal executive officer)	March 30, 2026

/s/ DOUGLAS L. BRUGGEMAN Douglas L. Bruggeman	Vice President-Finance, Chief Financial Officer and Treasurer (principal financial and accounting officer)	March 30, 2026

/s/ EDWARD M. KRESS Edward M. Kress	Director	March 30, 2026

/s/ CHARLES A. ELCAN Charles A. Elcan	Director	March 30, 2026

/s/ DAVID S. HARRIS David S. Harris	Director	March 30, 2026

/s/ MERVYN L. ALPHONSO Mervyn L. Alphonso	Director	March 30, 2026

/s/ LEE I. FISHER Lee I. Fisher	Director	March 30, 2026

/s/ ANNE C. MACMILLAN Anne C. MacMillan	Director	March 30, 2026

/s/ CHERYL L. BUSTOS Cheryl L. Bustos	Director	March 30, 2026

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