Form 10-Q REX AMERICAN RESOURCES For: Jul 31
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UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
WASHINGTON, D.C. 20549
FORM
(Mark One)
| QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 | |
| For the quarterly period ended | |
| OR | |
| TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 | |
| For the transition period from _________ to _________ |
Commission File Number
(Exact name of registrant as specified in its charter)
(State or other jurisdiction of incorporation or organization) | (I.R.S. Employer Identification Number) | ||
(Address of principal executive offices) | (Zip Code) |
(
(Registrant’s telephone number, including area code)
Securities registered pursuant to Section 12(b) of the Act:
| Title of each class | Trading Symbol(s) | Name of each exchange on which registered |
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.
Indicate by check mark whether the registrant
has submitted electronically every Interactive Data File required to be submitted 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).
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 definition of “large accelerated filer”, “accelerated filer”, “smaller reporting company” and “emerging growth company” in Rule 12b-2 of the Exchange Act.
| Accelerated filer ☐ | ||
| Non-accelerated filer ☐ (Do not check if a smaller reporting company) | Smaller reporting company | |
| Emerging growth company | ||
If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ☐
Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).
Yes ☐ No
At the close of business on September 2,
2026, the registrant had
REX AMERICAN RESOURCES CORPORATION AND SUBSIDIARIES
INDEX
2
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 Resources, LLC and subsidiaries – REX owns 10.3% |
| Industry Terms: | |
| CI | Carbon Intensity |
| CO2 | Carbon dioxide |
| E-10 | Gasoline blended with up to 10% ethanol by volume |
| E-15 | Gasoline blended with up to 15% ethanol by volume |
| EACs | Energy Attribute Certificates |
| EPA | United States Environmental Protection Agency |
| FEOC | Foreign Entity of Concern |
| GHG | Greenhouse Gas |
| IRA | Inflation Reduction Act |
| IRC | Internal Revenue Code of 1986, as amended |
| IRC Section 45/Section 45 | IRC § 45 - Electricity Produced from Certain Renewable Resources, etc. |
| IRS | Internal Revenue Service |
| OBBBA | One Big Beautiful Bill Act |
| PHMSA | Pipeline and Hazardous Materials Safety Administration |
| RFS II | Renewable Fuel Standard II |
| RINs | Renewable Identification Number(s) |
| RVOs | Renewable Volume Obligations |
| Section 45Q/45Q | Section 45Q of the IRC |
| Section 45Z/45Z | Section 45Z of the IRC |
| 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 815 | ASC 815, “Derivatives and Hedging” |
| ASC 820 | ASC 820, “Fair Value Measurements and Disclosures” |
| ASU | Accounting Standards Update |
| ASU 2025-10 | ASU 2025-10, “Accounting for Government Grants Received by Business Entities” |
| FASB | Financial Accounting Standards Board |
| SG&A | Selling, general, and administrative |
| RSUs | Restricted stock units |
| TSR | Total shareholder return |
3
Forward-Looking Statements
This Form 10-Q 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 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 of the Company’s Annual Report on Form 10-K for the fiscal year ended January 31, 2026 (File No. 001-09097).
4
PART I. FINANCIAL INFORMATION
Item 1. Financial Statements
REX AMERICAN RESOURCES CORPORATION AND SUBSIDIARIES
Consolidated Balance Sheets
Unaudited
(In Thousands)
| July 31, | January 31, | |||||||
| 2026 | 2026 | |||||||
| Assets | ||||||||
| Current assets: | ||||||||
| Cash and cash equivalents | $ | $ | ||||||
| Short-term investments | ||||||||
| Accounts receivable | ||||||||
| Inventory | ||||||||
| Refundable income taxes | ||||||||
| Prepaid expenses and other | ||||||||
| Total current assets | ||||||||
| Property and equipment, net | ||||||||
| Operating lease right-of-use assets | ||||||||
| Finance lease right-of-use assets | ||||||||
| Other assets | ||||||||
| Equity method investment | ||||||||
| Total assets | $ | $ | ||||||
| Liabilities and equity | ||||||||
| Current liabilities: | ||||||||
| Accounts payable – trade (includes $ | $ | $ | ||||||
| Current operating lease liabilities | ||||||||
| Current finance lease liabilities | ||||||||
| Accrued expenses and other current liabilities | ||||||||
| Total current liabilities | ||||||||
| Long-term liabilities: | ||||||||
| Deferred taxes | ||||||||
| Long-term operating lease liabilities | ||||||||
| Long-term finance lease liabilities | ||||||||
| Other long-term liabilities | ||||||||
| Total long-term liabilities | ||||||||
| Equity: | ||||||||
| REX shareholders’ equity: | ||||||||
| Common stock | ||||||||
| Paid-in capital | ||||||||
| Retained earnings | ||||||||
| Treasury stock | ( | |||||||
| Total REX shareholders’ equity | ||||||||
| Noncontrolling interests | ||||||||
| Total equity | ||||||||
| Total liabilities and equity | $ | $ | ||||||
The accompanying notes are an integral part of these unaudited consolidated financial statements.
5
REX AMERICAN RESOURCES CORPORATION AND SUBSIDIARIES
Consolidated Statements of Operations
Unaudited
(In Thousands, Except Per Share Amounts)
| Three Months Ended July 31, | Six Months Ended July 31, | |||||||||||||||
| 2026 | 2025 | 2026 | 2025 | |||||||||||||
| Net sales and revenue | $ | $ | $ | $ | ||||||||||||
| Production tax credit income | ||||||||||||||||
| Cost of sales (includes $ | ||||||||||||||||
| Gross profit | ||||||||||||||||
| Selling, general and administrative expenses | ( | ( | ( | ( | ||||||||||||
| Equity in income of unconsolidated affiliates | ||||||||||||||||
| Interest and other income, net | ||||||||||||||||
| Income before income taxes | ||||||||||||||||
| Provision for income taxes | ( | ( | ( | ( | ||||||||||||
| Net income | ||||||||||||||||
| Net income attributable to noncontrolling interests | ( | ( | ( | ( | ||||||||||||
| Net income attributable to REX common shareholders | $ | $ | $ | $ | ||||||||||||
| Weighted average shares outstanding – basic and diluted | ||||||||||||||||
| Basic and diluted net income per share attributable to REX common shareholders | $ | $ | $ | $ | ||||||||||||
The accompanying notes are an integral part of these unaudited consolidated financial statements.
6
REX AMERICAN RESOURCES CORPORATION AND SUBSIDIARIES
Consolidated Condensed Statements of Equity
For the Three and Six Months Ended July 31, 2026 and 2025
Unaudited
(In Thousands)
| REX Shareholders | ||||||||||||||||||||||||||||||||
| Common Shares Issued | Treasury | Paid-in | Retained | Noncontrolling | Total | |||||||||||||||||||||||||||
| Shares | Amount | Shares | Amount | Capital | Earnings | Interests | Equity | |||||||||||||||||||||||||
| Balance at January 31, 2026 | $ | $ | $ | $ | $ | $ | ||||||||||||||||||||||||||
| Net income | ||||||||||||||||||||||||||||||||
| Issuance of equity awards and stock-based compensation expense | ||||||||||||||||||||||||||||||||
| Balance at April 30, 2026 | ||||||||||||||||||||||||||||||||
| Net income | ||||||||||||||||||||||||||||||||
| Stock repurchases | ( | ( | ||||||||||||||||||||||||||||||
| Noncontrolling interests distributions and other | ( | ( | ||||||||||||||||||||||||||||||
| Issuance of equity awards and stock-based compensation expense | ||||||||||||||||||||||||||||||||
| Balance at July 31, 2026 | $ | $ | ( | $ | $ | $ | $ | |||||||||||||||||||||||||
Continued on the following page
7
REX AMERICAN RESOURCES CORPORATION AND SUBSIDIARIES
Consolidated Statements of Equity
Unaudited
(In Thousands)
Continued from the previous page
| REX Shareholders | ||||||||||||||||||||||||
| Common Stock Issued | Paid-in | Retained | Noncontrolling | Total | ||||||||||||||||||||
| Shares | Amount | Capital | Earnings | Interests | Equity | |||||||||||||||||||
| Balance at January 31, 2025 | $ | $ | $ | $ | $ | |||||||||||||||||||
| Net income | ||||||||||||||||||||||||
| Stock repurchases | ( | ( | ( | ( | ||||||||||||||||||||
| Noncontrolling interests distributions and other | ( | ( | ||||||||||||||||||||||
| Issuance of equity awards and stock-based compensation expense | ||||||||||||||||||||||||
| Balance at April 30, 2025 | ||||||||||||||||||||||||
| Net income | ||||||||||||||||||||||||
| Stock repurchases | ( | ( | ( | |||||||||||||||||||||
| Noncontrolling interests distributions and other | ( | ( | ||||||||||||||||||||||
| Issuance of equity awards and stock-based compensation expense | ||||||||||||||||||||||||
| Balance at July 31, 2025 | $ | $ | - | $ | $ | $ | ||||||||||||||||||
The accompanying notes are an integral part of these unaudited consolidated financial statements.
8
REX AMERICAN RESOURCES CORPORATION AND SUBSIDIARIES
Consolidated Statements of Cash Flows
Unaudited
(In Thousands)
| Six Months Ended July 31, | ||||||||
| 2026 | 2025 | |||||||
| Cash flows from operating activities: | ||||||||
| Net income | $ | $ | ||||||
| Adjustments to reconcile net income to net cash provided by operating activities: | ||||||||
| Depreciation | ||||||||
| Noncash operating lease expense | ||||||||
| Amortization of finance lease right-of-use assets | ||||||||
| Stock-based compensation expense | ||||||||
| Income from equity method investments | ( | ( | ||||||
| Dividends received from equity method investments | ||||||||
| Interest income from investments | ( | ( | ||||||
| Loss on disposal of property and equipment – net | ||||||||
| Deferred income taxes | ||||||||
| Changes in assets and liabilities: | ||||||||
| Accounts receivable | ( | ( | ||||||
| Inventory | ( | |||||||
| Prepaid expenses and other | ( | ( | ||||||
| Refundable income taxes | ( | |||||||
| Accounts payable – trade | ( | ( | ||||||
| Long-term taxes payable | ||||||||
| Accrued expenses and other liabilities | ( | ( | ||||||
| Net cash provided by operating activities | ||||||||
| Cash flows from investing activities: | ||||||||
| Capital expenditures | ( | ( | ||||||
| Purchases of short-term investments | ( | ( | ||||||
| Maturities of short-term investments | ||||||||
| Proceeds from disposal of real estate and property and equipment | ||||||||
| Deposits | ( | |||||||
| Net cash (used in) provided by investing activities | ( | |||||||
| Cash flows from financing activities: | ||||||||
| Treasury stock acquired | ( | ( | ||||||
| Noncontrolling interests distributions and other | ( | ( | ||||||
| Principal paid on finance lease liabilities | ( | |||||||
| Net cash used in financing activities | ( | ( | ||||||
| Net (decrease) increase in cash and cash equivalents | ( | |||||||
| Cash and cash equivalents, beginning of period | ||||||||
| Cash and cash equivalents, end of period | $ | $ | ||||||
| Non-cash investing activities – Accrued capital expenditures | $ | $ | ||||||
| Non-cash investing activities – Capital additions transferred from prepaid expenses | $ | $ | ||||||
| Non-cash financing activities – Stock awards accrued | $ | $ | ||||||
| Non-cash financing activities – Stock awards issued | $ | $ | ||||||
| Non-cash financing activities – Excise tax on stock repurchases accrued | $ | $ | ||||||
| Operating right-of-use assets acquired and liabilities incurred upon lease commencement | $ | $ | ||||||
| Finance right-of-use assets acquired and liabilities incurred upon lease commencement | $ | $ | ||||||
The accompanying notes are an integral part of these unaudited consolidated financial statements.
9
REX AMERICAN RESOURCES CORPORATION AND SUBSIDIARIES
NOTES TO UNAUDITED CONSOLIDATED FINANCIAL STATEMENTS
July 31, 2026
Note 1. Consolidated Financial Statements
References to the Company – References to “REX” or the “Company” in the consolidated financial statements and in these notes to the consolidated financial statements refer to REX American Resources Corporation, a Delaware corporation, and its majority and wholly owned subsidiaries.
The consolidated financial statements included in this report have been prepared by the Company, without audit, pursuant to the rules and regulations of the Securities and Exchange Commission and include, in the opinion of management, all adjustments necessary to state fairly the information set forth therein. Any such adjustments were of a normal recurring nature. Certain information and footnote disclosures normally included in financial statements prepared in accordance with accounting principles generally accepted in the United States of America have been omitted pursuant to such rules and regulations, although the Company believes that the disclosures are adequate to make the information presented not misleading. Financial information as of January 31, 2026 included in these financial statements has been derived from the audited consolidated financial statements included in the Company’s Annual Report on Form 10-K for the year ended January 31, 2026 (fiscal year 2025). These unaudited consolidated financial statements should be read in conjunction with the consolidated financial statements and the notes thereto included in the Company’s Annual Report on Form 10-K for the year ended January 31, 2026. The results of operations for the interim periods are not necessarily indicative of the results to be expected for the year.
Basis of Consolidation – The consolidated financial statements in this report include the operating results and financial position of the Company. All intercompany balances and transactions have been eliminated. The Company consolidates the results of its wholly owned and majority owned subsidiaries. The Company includes the results of operations of One Earth in its Consolidated Statements of Operations on a delayed basis of one month as One Earth has a fiscal year end of December 31.
Common Stock – On May 28, 2026,
shareholders adopted an amendment to the Certificate of Incorporation to increase the Company’s authorized common stock from
Stock Split – On August 26, 2025,
the Board of Directors of the Company adopted resolutions declaring a split of the Company’s Common Stock to be effectuated
in the form of a
Nature of Operations – The Company
has
10
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 are aggregated into one reporting segment.
Note 2. Accounting Policies
The interim consolidated financial statements have been prepared in accordance with the accounting policies described in the notes to the consolidated financial statements included in the Company’s fiscal year 2025 Annual Report on Form 10-K. While management believes that the procedures followed in the preparation of interim financial information are reasonable, the accuracy of some estimated amounts is dependent upon facts that will exist or calculations that will be accomplished at fiscal year-end. Examples of such estimates include accrued liabilities, such as management bonuses, and the provision for income taxes. Any adjustments pursuant to such estimates during the quarter were of a normal recurring nature. Actual results could differ from those estimates.
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 and Cash Equivalents
Cash and cash equivalents includes bank deposits as well as short-term, highly liquid investments with original maturities of three months or less. The carrying amount of cash equivalents approximates fair value.
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 July 31, 2026 and January 31, 2026, the Company believes that all amounts are collectible and an allowance
for credit losses was not considered necessary. The balance of accounts receivable at January 31, 2025 was $
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.
11
Change in Accounting Principles
The Company has determined that it qualifies for clean fuel production tax credits allowable under the IRA and OBBBA. The benefit recognized is determined based on the Company’s CI score. The Company intends on utilizing the tax credits earned in fiscal year 2025 to offset taxes due and payable. As of July 31, 2026, the Company currently intends on selling the tax credits earned in fiscal year 2026.
Effective February 1, 2026, the Company elected to early adopt ASU 2025-10, “Accounting for Government Grants Received by Business Entities” and changed its accounting policy for Section 45Z tax credits. The Company determined the income model under ASU 2025-10 is preferable to better align with monetization opportunities in the future. The Company will record the tax credits earned under the income model of ASU 2025-10 as “Production tax credit income”, included within gross profit on the Consolidated Statements of Operations and within “Other assets” on the Consolidated Balance Sheets.
The Company determined that the change in accounting policy requires retrospective application. The Company did not record any Section 45Z tax credits until the fourth quarter of fiscal year 2025, and as such, there is no impact to the first six months of fiscal year 2025. Additionally, as the Company does not intend to monetize the credits earned in fiscal year 2025, the balance sheet classification as a deferred tax asset within “Other assets” remains appropriate. Further, there is no impact to the prior period equity balances as the retrospective adjustments result in an increase in net income attributable to noncontrolling interests, offset by an increase in distributions to noncontrolling interests. Accordingly, no retrospective adjustments to the balance sheet are required.
Below is a summary of reclassifications made to the Consolidated Statements of Operations for the year ended January 31, 2026 (amounts in thousands):
| Year Ended January 31, 2026 | ||||||||||||
| As Previously Reported | Effect of Change | As Currently Reported | ||||||||||
| Production tax credit income | $ | $ | $ | |||||||||
| Gross profit | $ | $ | $ | |||||||||
| Income before income taxes | $ | $ | $ | |||||||||
| Benefit (provision) for income taxes | $ | $ | ( | $ | ( | |||||||
| Net income | $ | $ | $ | |||||||||
| Net income attributable to noncontrolling interests | $ | ( | $ | ( | $ | ( | ||||||
| Net income attributable to REX common shareholders | $ | $ | $ | |||||||||
12
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.
Selling, General and Administrative Expenses
The Company includes non-production related costs such as professional fees, operating lease expense, and certain payroll in SG&A expenses.
Financial Instruments
Certain of the forward corn and natural gas purchase contracts 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 corn that will be delivered in quantities expected to be used by the Company and sales of ethanol, distillers grains and distillers corn oil in quantities expected to be sold by the Company over a reasonable period of time in the normal course of business.
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 sales 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 designate any of its derivative instruments as cash flow or fair value hedges.
Income Taxes
The Company applies an effective tax rate to
interim periods that is consistent with the Company’s estimated annual tax rate as adjusted for discrete items impacting the interim
periods. 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 basis 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
paid income taxes of approximately $
As of July 31, 2026 and January 31, 2026, total
unrecognized tax benefits were approximately $
13
benefits recorded, the provision for income taxes would be reduced
by approximately $
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-products. Inventory is permanently written down in 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 did
The components of inventory are as follows (amounts in thousands):
| July 31, 2026 | January 31, 2026 | |||||||
| Ethanol and other finished goods | $ | $ | ||||||
| Work in process | ||||||||
| Corn and other raw materials | ||||||||
| Total | $ | $ | ||||||
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
In accordance with ASC 360-10 “Impairment or Disposal of Long-Lived Assets”, the carrying value of long-lived assets is assessed for recoverability by management when changes in circumstances indicate that the carrying amount may not be recoverable. The Company did not identify any indicators of impairment or record any impairment charges during the first six months of fiscal year 2026 or fiscal year 2025.
The Company tests for
recoverability of an asset group by comparing its carrying amount to its estimated undiscounted future cash flows. If the carrying
amount exceeds its estimated undiscounted future
14
cash flows, the Company recognizes an impairment charge for the amount by which the asset group’s carrying amount exceeds its fair value, if any.
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 a limited liability
company in which it has a less than
The Company periodically evaluates its investments for impairment due to declines in market value considered to be other than temporary. Such impairment evaluations include 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.
Recently Issued Accounting Standards
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. This ASU is effective for the Company’s fiscal year ended January 31, 2028. The Company is currently evaluating the impact of this ASU.
In May 2026, the FASB issued ASU 2026-02, “Environmental Credits and Environmental Credit Obligations (Topic 818)”, which establishes accounting and disclosure requirements for environmental credits and environmental credit obligations. The Company’s operations involve environmental credits, including RINs and EACs. This ASU is effective for the Company’s fiscal year ended January 31, 2029. The Company is currently evaluating the impact of the ASU on its accounting policies, financial statement presentation, and disclosures. The Company has not yet determined the impact that adoption of this standard will have on its consolidated financial statements and related disclosures.
15
Note 3. 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 or truck 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 concurrently with revenue producing activities are excluded from net sales and revenue.
The majority of the Company’s sales have payment
terms ranging from
The following tables shows disaggregated revenue by product (amounts in thousands):
| Three Months Ended July 31, | Six Months Ended July 31, | |||||||||||||||
| 2026 | 2025 | 2026 | 2025 | |||||||||||||
| Ethanol | $ | $ | $ | $ | ||||||||||||
| Dried distillers grains | ||||||||||||||||
| Distillers corn oil | ||||||||||||||||
| Modified distillers grains | ||||||||||||||||
| Derivative financial instruments gains (losses) | ( | |||||||||||||||
| Other | ||||||||||||||||
| Total | $ | $ | $ | $ | ||||||||||||
Note 4. Leases
Operating Leases
At July 31, 2026, the Company had lease agreements, as lessee, for railcars. All of 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 of 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.
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The components of lease expense, classified as SG&A expenses on the Consolidated Statement of Operations and total cash paid for amounts included in the measurement of lease liabilities are as follows (amounts in thousands):
| Three Months Ended July 31, | Six Months Ended July 31, | |||||||||||||||
| 2026 | 2025 | 2026 | 2025 | |||||||||||||
| Operating lease expense | $ | $ | $ | $ | ||||||||||||
| Variable lease expense | ||||||||||||||||
| Total lease expense | $ | $ | $ | $ | ||||||||||||
| Total cash paid in measurement of lease liability | $ | $ | $ | $ | ||||||||||||
The following table is a summary of future minimum rentals on such leases at July 31, 2026 (amounts in thousands):
| Years Ended January 31, | Minimum Rentals | |||
| Remainder of 2027 | $ | |||
| 2028 | ||||
| 2029 | ||||
| 2030 | ||||
| 2031 | ||||
| Total | ||||
| Less: present value discount | ||||
| Operating lease liabilities | $ | |||
At July 31, 2026, the weighted average remaining
lease term is
At January 31, 2026, the weighted average remaining
lease term was
Finance Lease
At July 31, 2026, the Company had one lease agreement
that was classified as a finance lease for an electrical substation facility. Prepayments totaling $
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output was transferred to the Company just before the end of the
first quarter of fiscal year 2025, with monthly lease expense commencing in the second quarter of fiscal year 2025. Expense related
to this lease was $
The weighted average remaining lease term for
the finance lease was
The following table is a summary of future minimum rentals on the lease at July 31, 2026 (amounts in thousands):
| Years Ended January 31, | Minimum Rentals | |||
| Remainder of 2027 | $ | |||
| 2028 | ||||
| 2029 | ||||
| 2030 | ||||
| 2031 | ||||
| Thereafter | ||||
| Total | ||||
| Less: present value discount | ||||
| Finance lease liabilities | $ | |||
Note 5. Fair Value
The Company applies ASC 820, which provides a framework for measuring fair value under accounting principles generally accepted in the United States of America. This accounting standard 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 instruments at fair value.
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
18
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.
To ensure the prudent application of estimates and management judgment in determining the fair value of derivative assets and liabilities, investments 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 on a recurring and nonrecurring basis at July 31, 2026 are summarized below (amounts in thousands):
| Level 1 | Level 2 | Level 3 | Fair Value | |||||||||||||
| Forward purchase contracts asset (1) | $ | $ | $ | $ | ||||||||||||
| Commodity futures asset (2) | ||||||||||||||||
| Production tax credit asset (3) | ||||||||||||||||
| Total assets | $ | $ | $ | $ | ||||||||||||
| Forward purchase contracts liability (4) | $ | $ | $ | $ | ||||||||||||
Financial assets and liabilities measured at fair value on a recurring basis at January 31, 2026 are summarized below (amounts in thousands):
| Level 1 | Level 2 | Level 3 | Fair Value | |||||||||||||
| Forward purchase contracts asset (1) | $ | $ | $ | $ | ||||||||||||
| Commodity futures asset (2) | ||||||||||||||||
| Total assets | $ | $ | $ | $ | ||||||||||||
| Forward purchase contracts liability (4) | $ | $ | $ | $ | ||||||||||||
| (1) | ||
| (2) | ||
| (3) |
19
| (4) |
There were
| Fair Value as of April 30, 2026 | $ | |||
| Generated transferable tax credits | ||||
| Fair value as of July 31, 2026 | $ |
Note 6. Property and Equipment
The components of property and equipment are as follows for the periods presented (amounts in thousands):
| July 31, 2026 | January 31, 2026 | |||||||
| Land and improvements | $ | $ | ||||||
| Buildings and improvements | ||||||||
| Machinery, equipment, and fixtures | ||||||||
| Construction in progress | ||||||||
| Total property and equipment | ||||||||
| Less: Accumulated depreciation | ( | ( | ||||||
| Total | $ | $ | ||||||
Note 7. Other Assets
The components of other assets are as follows for the periods presented (amounts in thousands):
| July 31, 2026 | January 31, 2026 | |||||||
| Deferred taxes | $ | $ | ||||||
| Production tax credit | | |||||||
| Other | ||||||||
| Total | $ | $ | ||||||
20
Note 8. Accrued Expenses and Other Current Liabilities
The components of accrued expenses and other current liabilities are as follows for the periods presented (amounts in thousands):
| July 31, 2026 | January 31, 2026 | |||||||
| Accrued payroll and related items | $ | $ | ||||||
| Accrued utility charges | ||||||||
| Accrued capital expenditures | ||||||||
| Accrued transportation related items | ||||||||
| Accrued real estate taxes | ||||||||
| Forward purchase contracts | ||||||||
| Other | ||||||||
| Total | $ | $ | ||||||
Note 9. 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 (that are not accounted for under the “normal purchases and normal sales” scope exemption of ASC 815) and the line items on the Consolidated Balance Sheets in which the fair values are reflected (amounts in table in thousands):
| Asset Derivatives Fair Value | Liability Derivatives Fair Value | |||||||||||||||
| July 31, 2026 | January 31, 2026 | July 31, 2026 | January 31, 2026 | |||||||||||||
| Forward purchase contracts (1) | $ | $ | $ | $ | ||||||||||||
| Cash collateral balance (2) | $ | $ | $ | $ | ||||||||||||
| Commodity futures (3) | ||||||||||||||||
| Net position with broker | $ | $ | $ | $ | ||||||||||||
| Total | $ | $ | $ | $ | ||||||||||||
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| (1) | ||
| (2) | ||
| (3) | ||
| See Note 5 which contains fair value information related to derivative financial instruments. |
The following table provides information about gains (losses) recognized in income from 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 three and six months ended July 31, 2026 and 2025 (amounts in thousands):
| Three Months Ended July 31, | Six Months Ended July 31, | |||||||||||||||
| 2026 | 2025 | 2026 | 2025 | |||||||||||||
| Net sales | $ | $ | $ | ( | $ | |||||||||||
| Cost of sales | $ | ( | $ | $ | ( | $ | ||||||||||
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Note 10. Investments
Short-term Investments
At July 31, 2026, the Company owned United States Treasury
Bills (classified as short-term investments) that had an amortized cost, or carrying value, of approximately $
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 $
Equity Method Investment in Big River
The following table summarizes the Company’s equity method investment at July 31, 2026 and January 31, 2026 (dollars in thousands):
| Carrying Amount | ||||||||||
| Entity | Ownership Percentage | July 31, 2026 | January 31, 2026 | |||||||
| Big River | $ | $ | ||||||||
Undistributed earnings of the Company’s equity method
investee totaled approximately $
Summarized financial information for the Company’s equity method investee is presented in the following table for the periods presented (amounts in thousands):
| Three Months Ended July 31, | Six Months Ended July 31, | |||||||||||||||
| 2026 | 2025 | 2026 | 2025 | |||||||||||||
| Net sales and revenue | $ | $ | $ | $ | ||||||||||||
| Production tax credit income | $ | $ | $ | $ | ||||||||||||
| Gross profit | $ | $ | $ | $ | ||||||||||||
| Depreciation expense | $ | $ | $ | $ | ||||||||||||
| Net income | $ | $ | $ | $ | ||||||||||||
| Net income attributable to members | $ | $ | $ | $ | ||||||||||||
23
Note 11. 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
On May 28, 2026, shareholders approved
the REX American Resources Corporation 2026 Incentive Plan, which reserves a total of
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 liability and equity awards in its consolidated financial statements over the requisite service period on a straight-line basis.
At July 31, 2026,
Restricted Stock Awards
As a component of their compensation, restricted stock has been granted in the past to directors and certain employees at the closing market price of REX common stock on the grant date. In addition, one quarter of executives’ incentive compensation is payable by an award of restricted stock based on the then closing market price of REX common stock on the grant date. The Company’s board of directors has determined that the grant date will be June 15th, or the next business day if June 15th is not a business day, for all grants of restricted stock.
Based on retirement eligibility provisions,
a portion of restricted stock grants were expensed at grant date, based on grant date fair value, thus considered vested for accounting
purposes. At July 31, 2026,
24
The following tables summarize legally unvested restricted stock award activity for the periods presented:
| Six Months Ended July 31, 2026 | |||||||||||
| Shares | Weighted Average Grant Date Fair Value (000’s) | Weighted Average Remaining Vesting Term (in years) | |||||||||
| Non-vested at January 31, 2026 | $ | ||||||||||
| Granted | |||||||||||
| Forfeited | |||||||||||
| Vested | |||||||||||
| Non-vested at July 31, 2026 | $ | ||||||||||
| Six Months Ended July 31, 2025 | |||||||||||
| Shares | Weighted Average Grant Date Fair Value (000’s) | Weighted Average Remaining Vesting Term (in years) | |||||||||
| Non-vested at January 31, 2025 | $ | ||||||||||
| Granted | |||||||||||
| Forfeited | |||||||||||
| Vested | |||||||||||
| Non-vested at July 31, 2025 | $ | ||||||||||
Restricted Stock Units
In May 2022, the Company issued a
total of
In June 2026, the Company issued
a total of
25
to the Company during the three year performance period ending January 31, 2029. The number of RSUs eligible to vest ranges from to , depending on actual performance during the performance period. The shares are valued using the grant date share price using an estimate as of July 31, 2026 for the value of 45Z and 45Q credits anticipated to be earned.
As of July 31, 2026, the Company
estimates the RSUs will vest at For both the three and six month periods ended July 31, 2026, the Company recognized
compensation cost of approximately $
The Company determined there to be
Note 12. Income Taxes
The Company’s income tax provision was approximately
$
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.
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 allowed for 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 financial results. 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 ($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 $0.02 or $0.10 earned upon achieving a CI score below 47.5, subject to annual inflation adjustments. The Company believes that it is more-likely-than-not that applicable prevailing wage requirements will be met for 2025 and 2026 for its consolidated ethanol plants and has calculated the credit at the applicable credit rate based on its CI score for fiscal 2025 and its estimated CI score for the first six months of fiscal 2026, after the purchase of EACs.
26
Effective February 1, 2026, the Company elected to early adopt ASU 2025-10 and changed its accounting policy for Section 45Z tax credits. The Company determined the income model under ASU 2025-10 is preferable to better align with monetization opportunities in the future. The Company will record the tax credits earned under the income model of ASU 2025-10 as “Production tax credit income”, included within gross profit on the Consolidated Statements of Operations and within “Other assets” on the Consolidated Balance Sheets.
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 years ended January 31, 2014 and prior. The Company is currently finalizing, as an agreement in principle 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.
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.
A reconciliation of the beginning and ending amount of unrecognized tax benefits, including interest and penalties, is as follows (amounts in thousands):
| Six Months Ended July 31, | |||||||
| 2026 | 2025 | ||||||
| Unrecognized tax benefits, beginning of period | $ | $ | |||||
| Changes for prior years’ tax positions | |||||||
| Changes for current year tax positions | |||||||
| Unrecognized tax benefits, end of period | $ | $ | |||||
At July 31, 2026 and January 31, 2026 the unrecognized tax benefits were included within the following lines on the accompanying Consolidated Balance Sheets (amounts in thousands):
| July 31, 2026 | January 31, 2026 | |||||||
| Refundable income taxes | $ | ( | ) | $ | ( | ) | ||
| Other long-term liabilities | ||||||||
| Unrecognized tax benefits, end of period | $ | $ | ||||||
Note 13. Commitments and Contingencies
The Company may be involved in various legal actions arising in the normal course of business, from time to time. After taking into consideration legal counsel’s evaluations of any such action(s),
27
management is of the opinion that their outcome will not have a material
adverse effect on the Company’s Consolidated Financial Statements. There were
At July 31, 2026, One Earth and NuGen had combined
forward purchase contracts for approximately
At July 31, 2026, One Earth and NuGen had combined
sales commitments for approximately
One Earth entered into a
At July 31, 2026, One Earth had signed non-cancelable
contracts for capital projects with approximately $
Note 14. Related-Party Transactions
During the second quarter of fiscal years 2026 and
2025, One Earth and NuGen purchased approximately $
28
Note 15. Segment Reporting
The Company has
The members of the Executive Committee, consisting of the Executive Chairman of the Board and the Chief Executive Officer, are the Company’s chief operating decision maker. 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 are aggregated into one reporting segment, each of which is reviewed in the same manner by the chief operating decision maker. 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.
29
The following tables set forth certain financial data for the Company’s reportable segment for the three and six month periods ended July 31, 2026 and 2025 (in thousands):
| Three Months Ended July 31, | Six Months Ended July 31, | |||||||||||||||
| 2026 | 2025 | 2026 | 2025 | |||||||||||||
| Net sales and revenue | ||||||||||||||||
| Ethanol and by-products | $ | $ | $ | $ | ||||||||||||
| Reconciling Item: Equity method ethanol investment | ( | ) | ( | ) | ( | ) | ( | ) | ||||||||
| Total consolidated net sales and revenue | $ | $ | $ | $ | ||||||||||||
| Production tax credit income | ||||||||||||||||
| Ethanol and by-products | $ | $ | $ | $ | ||||||||||||
| Reconciling Item: Equity method ethanol investment | ( | ) | ( | ) | ||||||||||||
| Total consolidated production tax credit income | $ | $ | $ | $ | ||||||||||||
| Cost of sales | ||||||||||||||||
| Ethanol and by-products: | ||||||||||||||||
| Cost of corn | $ | $ | $ | $ | ||||||||||||
| Other cost of sales (1) | ||||||||||||||||
| Reconciling Item: Equity method ethanol investment | ( | ) | ( | ) | ( | ) | ( | ) | ||||||||
| Total cost of sales | $ | $ | $ | $ | ||||||||||||
| Gross profit | ||||||||||||||||
| Ethanol and by-products | $ | $ | $ | $ | ||||||||||||
| Reconciling Item: Equity method ethanol investment | ( | ) | ( | ) | ( | ) | ( | ) | ||||||||
| Total consolidated gross profit | $ | $ | $ | $ | ||||||||||||
| Depreciation and amortization expense | ||||||||||||||||
| Ethanol and by-products | $ | $ | $ | $ | ||||||||||||
| Reconciling Item: Equity method ethanol investment | ( | ) | ( | ) | ( | ) | ( | ) | ||||||||
| Total consolidated depreciation and amortization expense | $ | $ | $ | $ | ||||||||||||
| Income before taxes | ||||||||||||||||
| Ethanol and by-products | $ | $ | $ | $ | ||||||||||||
| Reconciling Item: Equity method ethanol investment | ( | ) | ( | ) | ( | ) | ( | ) | ||||||||
| Total consolidated income before income taxes | ||||||||||||||||
| Provision for income taxes | ( | ) | ( | ) | ( | ) | ( | ) | ||||||||
| Total consolidated net income | $ | $ | $ | $ | ||||||||||||
| (1) |
30
Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations
Ethanol and By-Products
At July 31, 2026, we had investments in three ethanol limited liability companies, in two of which we have a majority ownership interest. The following table is a summary of ethanol entity ownership interests at July 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 | W. Burlington, IA | 10.3% |
| Big River Resources Galva, LLC | Galva, IL | 10.3% |
| Big River United Energy, LLC | Dyersville, IA | 5.7% |
| Big River Resources Boyceville, LLC | Boyceville, WI | 10.3% |
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 and trade negotiations 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
31
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 Energy, LLC Carbon Sequestration and Plant Expansion
One Earth Sequestration, LLC, a wholly owned subsidiary of One Earth, is in the developmental stage of a carbon sequestration project near the One Earth ethanol plant. In October 2022, we applied to the EPA for a Class VI injection well permit for three wells. The EPA issued a draft permit on August 17, 2026. This opens the public comment period through September 23, 2026. 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 compression facility and the 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, 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” relating to the impact of certain recently adopted legislation and certain recently proposed legislation that, if enacted, could affect 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 increase production to 200 million gallons per year. We continue to work to identify ways to further reduce our CI score at the One Earth plant with the intention of maximizing tax credits available under the IRA and OBBBA.
As of July 31, 2026, we had spent $59.1 million since inception toward the carbon sequestration project and were contractually obligated to spend an additional $0.3 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 outlined 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 July 31, 2026, we had spent $132.1 million since inception and were contractually committed to spend an additional $3.9 million toward plant capacity expansion at One Earth. We plan to pay for all expenditures from available cash.
32
The IRA, as amended by the OBBBA, created a new Clean Fuel Production Credit, available for calendar years 2025 – 2029 which, based on proposed rulemaking by the U.S. Department of Treasury, established a tax credit that utilizes a sliding scale where credits can be earned incrementally between $0.02 and $0.20 ($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 $0.02 or $0.10 credit earned upon achieving a CI score below 47.5, to incentivize further increases in plant efficiencies within the industry. The U.S. Department of the Treasury issued proposed rules on February 3, 2026 on qualification for 45Z tax credits. Based on proposed regulations, we recognized approximately $31.7 million and $26.0 million in 45Z tax credits through our consolidated subsidiaries for fiscal year 2025 and the first six months of fiscal year 2026, respectively. Public hearings were held on the proposed rules in 2026 and have yet to be finalized. Changes or clarifications to the proposed regulations, administrative guidance, or interpretations could result in an adjustment to management’s estimate of 45Z tax credits recognized. On June 12, 2026, the U.S. Department of Energy released an updated version of its 45ZCF-GREET model, removing indirect land-use change (“ILUC”) from the calculation.
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 under which the permits were issued to be unconstitutional. Summit Carbon Solutions is analyzing the decision and is contemplating next steps. These actions have delayed and could make the sequestration project for the NuGen facility more difficult for Summit Carbon Solutions to complete.
We plan to seek and evaluate various investment opportunities, including ethanol and/or energy related, carbon sequestration, agricultural or 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.
Refined Coal
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 approximately $58.2 million in federal production tax credits received through the ownership of this facility remain under IRS audit. That audit is in the process of being finalized, with the Company expecting to retain all federal production credits claimed for this project.
33
Critical Accounting Estimates
During the six months ended July 31, 2026, we did not change any of our critical accounting estimates as disclosed in our 2025 Annual Report on Form 10-K as filed with the Securities and Exchange Commission on March 30, 2026.
Fiscal Year
All references in this report to a particular fiscal year are to REX’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 2026” means the period February 1, 2026 to January 31, 2027. The Company includes the results of operations of One Earth and the equity investment income of Big River in its Consolidated Statements of Operations on a delayed basis of one month as One Earth and Big River have fiscal year ends of December 31.
Results of Operations
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 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. On August 3, 2026, the EPA issued one 100% waiver, two 50% waivers and determined three petitions to be ineligible from compliance years 2023 and 2024. On August 31, 2026, the remainder of the open SRE petitions from compliance year 2025, 34 in total, were decided with 18 full exemptions, 11 partial exemptions of 50% and five either denied or ruled ineligible, representing 1.8 billion RINs exempted. The EPA has proposed that 100% of the difference between previously projected and actual exempted volumes from the August 31, 2026 release be reallocated into the 2026 and 2027 RVOs. As a result of this announcement, the EPA has extended the 2025 RVO compliance date by 30 days to October 1, 2026. As of August 31, 2026, there were 8 SRE petitions pending from compliance years 2026-2027.
The RVO 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 issued emergency waivers allowing the sale of E-15 gasoline for the 2026 summer months. 2026 represents the fifth consecutive year for these emergency waivers. The EPA has not granted
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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. Efforts continue to pass legislation allowing for the sale of E-15 gasoline year-round. On May 13, 2026, House Resolution 1346 was passed by the House of Representative which would allow for year-round E-15 sales, but there is no set timeline for consideration in the Senate.
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 ($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 $0.02 or $0.10 credit earned upon achieving a CI score below 47.5. The IRA also raises the carbon capture tax credit under Section 45Q from $50 per metric ton to $85 per metric ton. 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 December 31, 2029, removing the indirect land-use change penalty for crop-based feedstocks beginning in 2026, limiting eligibility to feedstocks under the USMCA, imposing FEOC restrictions, and prohibiting negative emissions rates except from animal manure. It also modified the 45Q tax credit 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. On June 12, 2026, the U.S. Department of Energy released an updated version of its 45ZCF-GREET model to incorporate changes included in the OBBBA.
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 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 Safety and Aid for the Environment in Carbon Capture and Sequestration Act (SB 1289), enacted in 2024, 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 imposed 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. Following the expiration of the moratorium, we have begun preparing our application for submission to the Illinois Commerce Commission for our CO2 connector pipeline to the first injection well.
Illinois Senate Bill 1723, enacted in 2025, prohibits carbon sequestration activities over, under, or through the 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.
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The United States exported an estimated 2.2 billion gallons of ethanol in 2025, up from approximately 1.9 billion and 1.4 billion gallons in 2024 and 2023, respectively. Ethanol exports for the first six months of calendar year 2026 totaled 1.2 billion gallons, an increase of approximately 14% over the similar period of 2025, according to figures from the USDA Foreign Agricultural Services. In 2025 and 2024, an estimated 11.6 million 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. Distillers grains exports for the first six months of calendar year 2026 totaled 6.2 million metric tons, an increase of approximately 15% over the similar period of 2025. 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.
Based on the August 2026 report from the USDA, corn production is forecasted to be approximately 16.0 billion bushels in 2026. The average corn yield is forecasted to be 180.7 bushels per acre, with planted acres projected to be 96.7 million and harvested acres projected to be 88.6 million. The final 2025 USDA report estimated a record 2025 corn production of 17.0 billion bushels with an estimated 186.5 bushels per acre, on an estimated 91.3 million acres harvested.
The trends and uncertainties mentioned above could impact our future operating results in both positive and negative ways.
Comparison of Three and Six Months Ended July 31, 2026 and 2025
The following table summarizes our results from operations (amounts in thousands):
| Three Months Ended July 31, | Six Months Ended July 31, | |||||||||||||||
| 2026 | 2025 | 2026 | 2025 | |||||||||||||
| Net sales and revenue | $ | 168,493 | $ | 158,563 | $ | 324,992 | $ | 316,903 | ||||||||
| Production tax credit income | 18,410 | - | 25,959 | - | ||||||||||||
| Cost of sales | 133,603 | 144,244 | 268,580 | 288,242 | ||||||||||||
| Gross profit | $ | 53,300 | $ | 14,319 | $ | 82,371 | $ | 28,661 | ||||||||
| Income before income taxes | $ | 48,118 | $ | 12,097 | $ | 74,233 | $ | 25,723 | ||||||||
| Provision for income taxes | $ | (7,472) | $ | (2,769) | $ | (11,909) | $ | (5,723) | ||||||||
| Net income attributable to REX common shareholders | $ | 34,944 | $ | 7,111 | $ | 53,396 | $ | 15,789 | ||||||||
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The following table summarizes net sales and revenue by product group (amounts in thousands):
| Three Months Ended July 31, | Six Months Ended July 31, | |||||||||||||||
| 2026 | 2025 | 2026 | 2025 | |||||||||||||
| Ethanol | $ | 125,777 | $ | 123,312 | $ | 245,658 | $ | 247,709 | ||||||||
| Dried distillers grains | 24,163 | 21,260 | 48,326 | 43,546 | ||||||||||||
| Distillers corn oil | 17,589 | 12,509 | 30,545 | 22,388 | ||||||||||||
| Modified distillers grains | 811 | 1,251 | 1,845 | 2,873 | ||||||||||||
| Derivative financial instruments gains (losses) | 62 | 201 | (1,513) | 218 | ||||||||||||
| Other | 91 | 30 | 131 | 169 | ||||||||||||
| Total | $ | 168,493 | $ | 158,563 | $ | 324,992 | $ | 316,903 | ||||||||
The following table summarizes selected operating data:
| Three Months Ended July 31, | Six Months Ended July 31, | |||||||||||||||
| 2026 | 2025 | 2026 | 2025 | |||||||||||||
| Average selling price per gallon of ethanol (net of hedging) | $ | 1.78 | $ | 1.75 | $ | 1.72 | $ | 1.75 | ||||||||
| Gallons of ethanol sold (in millions) | 70.6 | 70.6 | 141.7 | 141.5 | ||||||||||||
| Average selling price per ton of dried distillers grains | $ | 166.55 | $ | 143.63 | $ | 161.03 | $ | 144.66 | ||||||||
| Tons of dried distillers grains sold | 145,081 | 148,017 | 300,113 | 301,027 | ||||||||||||
| Average selling price per pound of distillers corn oil | $ | 0.72 | $ | 0.54 | $ | 0.63 | $ | 0.50 | ||||||||
| Pounds of distillers corn oil sold (in millions) | 24.3 | 23.1 | 48.2 | 44.5 | ||||||||||||
| Average selling price per ton of modified distillers grains | $ | 65.10 | $ | 64.41 | $ | 71.24 | $ | 69.21 | ||||||||
| Tons of modified distillers grains sold | 12,465 | 19,421 | 25,892 | 41,515 | ||||||||||||
Net sales and revenue in the quarter ended July 31, 2026 increased approximately 6% compared to the prior fiscal year second quarter. Net sales and revenue in the six months ended July 31, 2026 increased approximately 3% compared to the first six months of fiscal year 2025.
Ethanol revenue, net of hedging, increased 2% in the second quarter of fiscal year 2026 compared to the second quarter of fiscal year 2025 as the selling price per gallon increased 2%, while gallons sold remained consistent. Ethanol revenue, net of hedging, decreased 2% in the first six months of fiscal year 2026 compared to the first six months of fiscal year 2025 as the selling price per gallon decreased 2%, while gallons sold remained consistent. Ethanol pricing is affected by many factors, including overall market supply and demand, as well as corn and gasoline pricing.
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Dried distillers grains revenue increased 14% in the second quarter of fiscal year 2026 compared to the second quarter of fiscal year 2025 as there was a 16% increase in the average price per ton sold, offset slightly by a 2% decrease in tons sold. Dried distillers grains revenue increased 11% in the first six months of fiscal year 2026 compared to the first six months of fiscal year 2025 as there was an 11% increase in the average price per ton sold, while tons sold remained consistent. The increase in the dried distillers grains selling price primarily reflects increased soymeal prices, which are often correlated with the price of distillers grains, as well as increased export demand.
Distillers corn oil revenue increased approximately 41% in the second quarter of fiscal year 2026 compared to the second quarter of fiscal year 2025 as the selling price per pound increased 33% and the amount of pounds sold increased 5%. Distillers corn oil revenue increased approximately 36% in the first six months of fiscal year 2026 compared to the first six months of fiscal year 2025 as the selling price per pound increased 26% and the amount of pounds sold increased 8%. The corn oil yield per bushel ground improved at our consolidated ethanol plants in the three and six month periods ended July 31, 2026, relative to the comparable periods in fiscal 2025. The increase in the distillers corn oil selling price resulted primarily from fluctuations in demand in the renewable biodiesel market.
Modified distillers grains revenue decreased 35% in the second quarter of fiscal year 2026 compared to the second quarter of fiscal year 2025 as the amount of tons sold decreased by 36%, offset partially with a 1% increase in the average selling price per ton sold. Modified distillers grains revenue decreased 36% in the first six months of fiscal year 2026 compared to the first six months of fiscal year 2025 as the amount of tons sold decreased by 38%, offset partially with a 3% increase in the average selling price per ton sold. The increase in the modified distillers grains selling price primarily reflects increased soymeal prices, as well as fluctuations in local demand. Our consolidated plants’ decisions to sell modified or dried distillers grains fluctuate from time to time based upon local market conditions.
The Company has determined that it qualifies for clean fuel production tax credits allowable under the IRA and OBBBA. The benefit recognized is determined based on the Company’s CI score to date. The Company recorded $18.4 million and $26.0 million in 45Z production tax credit income during the three months ended and six months ended July 31, 2026, respectively, and did not record any in the comparable prior fiscal year periods as proposed regulations had not yet been issued. Of the credits recorded in the three months ended July 31, 2026, $5.4 million represented incremental production tax credit income related to the previous quarter as the Company determined it now anticipates monetizing credits earned in fiscal year 2026 and began recognizing the year-to-date credits at a higher rate based upon the revised 45ZCF-GREET model released removing indirect land-use change from the carbon intensity calculation.
Cost of sales decreased 7% in the quarter ended July 31, 2026, compared to the prior fiscal year second quarter. Corn accounted for approximately 77% ($102.3 million) of our cost of sales during the second quarter of fiscal year 2026 compared to approximately 74% ($106.5 million) during the second quarter of fiscal year 2025. Natural gas accounted for approximately 4% ($5.4 million) of our cost of sales during the second quarter of fiscal year 2026 and 4% ($5.7 million) in the second quarter of fiscal year 2025. Cost of sales decreased 7% in the six months ended July 31, 2026, compared to the first six months of fiscal year 2025. Corn accounted for approximately 76% ($204.0 million) of our cost of sales during the first six months of fiscal year 2026 compared to approximately 74% ($212.9 million) during the first six months of fiscal year 2025. Natural gas accounted for approximately 5% ($14.1 million) of our cost of sales during the first six months of fiscal year 2026 and 5% ($13.8 million) in the first six months of fiscal year 2025.
As a result of the foregoing, gross profit for the second quarter of fiscal year 2026 increased approximately $39.0 million compared to the prior fiscal year second quarter. Gross profit for the first six
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months of fiscal year 2026 increased approximately $53.7 compared to the first six months of fiscal year 2025.
We attempt to match quantities of ethanol, distillers grains and distillers corn oil sales contracts with an appropriate quantity of corn purchase contracts over a given time period when we can obtain a satisfactory 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 sales 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 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 swap contracts, in conjunction with certain of our corn procurement activities and commodity marketing activities.
SG&A expenses for the second quarter of fiscal year 2026 were approximately $15.6 million (9.3% of net sales and revenue), an increase of approximately $9.4 million or 152% from approximately $6.2 million (3.9% of net sales and revenue) for the second quarter of fiscal year 2025. SG&A expenses for the first six months of fiscal year 2026 were approximately $25.4 million (7.8% of net sales and revenue), an increase of approximately $13.2 million or 109% from approximately $12.1 million (3.8% of net sales and revenue) for the first six months of fiscal year 2025. The dollar increase compared to the prior year is partially related to a $4.7 million increase and $7.5 million increase in performance bonuses in the three and six months periods ended July 31, 2026, primarily attributable to the increase in net income. Additionally, there was an increase of $3.0 million related to restricted stock awards granted to certain executive officers in the second quarter of 2026, which were expensed upon issuance.
During the second quarter of fiscal year 2026, we recognized income from our equity investment in Big River of approximately $7.2 million compared to income of approximately $0.9 million for the second quarter of fiscal year 2025. In the second quarter of fiscal year 2026, approximately $1.8 million of our recognized income from Big River was from Section 45Z tax credits. During the first six months of fiscal year 2026, we recognized income from our equity investment in Big River of approximately $10.8 million compared to income of approximately $1.9 million for the first six months of fiscal year 2025. In the first six months of fiscal year 2026, approximately $3.6 million of our recognized income was from Section 45Z tax credits. Big River did not recognize any benefit from Section 45Z tax credits in the three and six month periods ended July 31, 2025 as proposed regulations had not yet been issued. Our investment in Big River, which has interests in four ethanol production plants, represents an effective ownership of approximately 40.8 million gallons of ethanol shipped in the trailing twelve months ended July 31, 2026. Due to the inherent volatility of commodity prices within the ethanol industry, we cannot predict the likelihood of future operating results from Big River being similar to historical results.
Interest and other income was approximately $3.2 million for the second quarter of fiscal year 2026 versus approximately $3.1 million for the second quarter of fiscal year 2025. Interest and other income was approximately $6.5 million for the first six months of fiscal year 2026 versus approximately $7.3 million for the first six months of fiscal year 2025. One of our consolidated ethanol plants recognized $0.6 million less in patronage income from an investment in a cooperative in the first six months fiscal year 2026
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($0.1 million) compared to the first six months of fiscal year 2025 ($0.7 million). We do not expect patronage income from this investment in a cooperative to be significant in future periods.
As a result of the foregoing, income before income taxes was approximately $48.1 million and $12.1 million for the second quarter of fiscal years 2026 and 2025, respectively. Income before income taxes was approximately $74.2 million and $25.7 million for the first six months of fiscal years 2026 and 2025, respectively.
The Company applies an effective tax rate to interim periods that is consistent with the Company’s estimated annual tax rate as adjusted for discrete items impacting the interim periods. Our income tax provision was approximately $7.5 million and $2.8 million for the three months ended July 31, 2026 and 2025, respectively. Our income tax provision was approximately $11.9 million and $5.7 million for the first six months of fiscal years 2026 and 2025, respectively.
As a result of the foregoing, net income was approximately $40.6 million for the second quarter of fiscal year 2026 compared to approximately $9.3 million for the second quarter of fiscal year 2025. Net income was approximately $62.3 million for the first six months of fiscal year 2026 compared to approximately $20.0 million for the first six months of fiscal year 2025.
Net income attributable to noncontrolling interests was approximately $5.7 million for the second quarter of fiscal year 2026 and $2.2 million for the second quarter of fiscal year 2025. Net income attributable to noncontrolling interests was approximately $8.9 million for the first six months of fiscal year 2026 and $4.2 million for the first six months of fiscal year 2025. These amounts represent the other owners’ share of the income of NuGen and One Earth.
As a result of the foregoing, net income attributable to REX common shareholders for the second quarter of fiscal year 2026 was approximately $34.9 million, compared to net income attributable to REX common shareholders of approximately $7.1 million for the second quarter of fiscal year 2025. Net income attributable to REX common shareholders from the first six months of fiscal year 2026 was approximately $53.4 million, compared to net income attributable to REX common shareholders of approximately $15.8 million for the first six months of fiscal year 2025.
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Liquidity and Capital Resources
Summary of Cash Flows and Working Capital (dollar amounts in thousands):
| Six Months Ended July 31, | ||||||||
| 2026 | 2025 | |||||||
| Net cash provided by operating activities | $ | 38,023 | $ | 12,808 | ||||
| Net cash (used in) provided by investing activities | $ | (131,495) | $ | 67,533 | ||||
| Net cash used in financing activities | $ | (3,934) | $ | (35,634) | ||||
| July 31, 2026 | January 31, 2026 | |||||||
| Working capital | $ | 391,539 | $ | 372,451 | ||||
| Current ratio | 6.9x | 5.9x | ||||||
Operating Activities
Net cash provided by operating activities was $38.0 million for the first six months of fiscal year 2026, compared to $12.8 million provided by operating activities in the prior year period.
Operating cash flows for the six month period ended July 31, 2026 reflected net income of $62.3 million and non-cash adjustments of $11.7 million, and consisted 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. Big River paid dividends to REX of approximately $2.0 million during the first six months of fiscal year 2026. These inflows were offset by various changes to working capital of $38.1 million during the first six months of fiscal year 2026, most significantly including:
| ● | Use of cash of $27.3 million from the increase in prepaid expenses and other, primarily as a result of the recording of production tax credit assets of $26.0 million in fiscal year 2026. | |
| ● | Use of cash of $8.8 million from the increase in accounts receivable as a result of the timing of products shipping and the receipt of customer payments at our consolidated ethanol plants. | |
| ● | Use of cash of approximately $3.9 million from the decrease in accrued expenses and other liabilities as a result of a reduction in the lease liability of $3.3 million from payments made during the year, and a decrease in accrued utilities of approximately $1.1 million. | |
| ● | Cash provided of $3.8 million from the decrease in refundable income taxes due primarily to the accrual of the federal taxes currently payable being more than the estimated federal tax payments made to date. While the Company has tax credits available to offset all amounts owed, the Company is limited to using tax credits for only 75% of federal taxes owed. |
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In fiscal year 2025, operating cash flow reflected net income of $20.0 million and non-cash adjustments of $11.4 million. Big River paid dividends to REX of approximately $2.5 million during the first six months of fiscal year 2025. These inflows were offset by various changes to working capital of approximately $21.1 million, most significantly caused by:
| ● | Use of cash of approximately $9.9 million due to a decrease in accounts payable, primarily related to the timing of inventory receipts and vendor payments. | |
| ● | Use of cash of approximately $5.5 million from the decrease in other liabilities primarily caused by a decrease in accrued payroll which used cash of approximately $4.4 million, due to the timing of annual bonus payments. Additionally, a decrease in the lease liability used cash of $3.0 million based on payments made during the quarter. These decreases are partially offset by an increase in other current liabilities of $1.9 million. | |
| ● | Use of cash of approximately $3.3 million due to an increase in accounts receivable as a result of the timing of products shipping and the receipt of customer payments at our consolidated ethanol plants. | |
| ● | Use of cash of $2.0 million from the increase in refundable income taxes due primarily to the accrual of the federal taxes currently payable being less than the estimated federal tax payments made to date. While the Company has tax credits available to offset all amounts owed, the Company is limited to using tax credits for only 75% of federal taxes owed. |
Investing Activities
Net cash used in investing activities was $131.5 million in the first six months of fiscal year 2026 versus $67.5 million provided in the first six months of fiscal year 2025. In fiscal 2026, capital expenditures totaled $35.0 million, primarily at One Earth, which includes the plant expansion project ($27.5 million) and carbon sequestration ($0.8 million). Treasury activity used net cash, as $320.8 million of purchases exceeded $224.0 million of maturities of short term investments.
In the first six months of fiscal year 2025, capital expenditures were $28.9 million, primarily for various capital projects at our consolidated ethanol plants, including $9.7 million for the expansion project at the One Earth facility and $2.1 million for the carbon sequestration project. Treasury activity provided net cash, as $90.7 million of purchases were more than offset by $187.0 million of maturities for short-term investments.
Financing Activities
Net cash used in financing activities was $3.9 million in the first six months fiscal year 2026, due to $2.2 million paid to noncontrolling interests holders and $1.6 million in repurchases of common shares. In the first six months of fiscal year 2025, financing outflows were $35.6 million, including $33.4 million for stock repurchases, and $2.3 million for payments to noncontrolling interests holders.
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Capital Resources
At July 31, 2026, working capital was $391.5 million with a current ratio of 6.9x. The Company continues to investigate various uses for our excess cash and short-term investments, including stock repurchases and potential investments in ethanol, energy, carbon sequestration, and agriculture-related ventures.
As of July 31, 2026, we had spent $59.1 million since inception and were contractually committed to spend an additional $0.3 million toward the carbon sequestration project. As of July 31, 2026, we had spent $132.1 million since inception and were contractually committed to spend an additional $3.9 million toward the plant capacity expansion project. For all projects, we currently anticipate spending $20 million to $30 million during the remainder of fiscal year 2026. We plan to pay for all expenditures from available cash.
At July 31, 2026, 2,320,385 shares remained
authorized for repurchase under the Company’s buyback program. Repurchases are generally made when management deems the shares
to trade at a discount to intrinsic value.
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Item 3. Quantitative and Qualitative Disclosures About Market Risk
We are exposed to the impact of market fluctuations associated with commodity prices as discussed below.
We manage a portion of our risk with respect to the volatility of commodity prices inherent in the ethanol industry by using forward fixed-price purchase and fixed-price sale contracts and exchange traded commodity futures contracts. Our remaining exposure to market risk, which includes the impact of our risk management activities resulting from our fixed-price purchase and sale contracts and derivatives, is based on the estimated effect on pre-tax income for the twelve months following July 31, 2026 and is as follows, assuming normal operating capacity (amounts in thousands):
| Commodity | Estimated Total Volume for 12 Months |
Unit of Measure | Decrease in Pre-tax Income From a 10% Adverse Change in Price | |||
| Ethanol | 320,000 | Gallons | $ 59,307 | |||
| Corn | 110,725 | Bushels | $ 42,713 | |||
| Distillers Grains | 725 | Tons | $ 10,032 | |||
| Distillers Corn Oil | 113,850 | Pounds | $ 7,528 | |||
| Natural Gas | 7,400 | MmBtu | $ 1,524 |
Item 4. 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 of the end of the period covered by this report. Based on that evaluation, the Chief Executive Officer and Chief Financial Officer concluded that our disclosure controls and procedures are effective 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 and is accumulated and communicated to our management, including our Chief Executive Officer and Chief Financial Officer, as appropriate, to allow timely decisions regarding required disclosure.
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.
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PART II. OTHER INFORMATION
Item 1. 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 1A. Risk Factors
There have been no material changes to the risk factors discussed in our Annual Report on Form 10-K for the year ended January 31, 2026.
Item 2. Unregistered Sales of Equity Securities and Use of Proceeds
The following table provides information with respect to the Company’s repurchase of its common stock during the period covered by this report:
| Issuer Purchases of Equity Securities | ||||||||||||||||
| Period | Total Number of Shares Purchased | Average Price Paid per Share | Total Number of Shares Purchased as Part of Publicly Announced Plans or Programs | Maximum Number of Shares that May Yet Be Purchased Under the Plans or Programs (1) | ||||||||||||
| May 1-31, 2026 | - | $ | - | - | 2,357,186 | |||||||||||
| June 1-30, 2026 | 36,801 | 42.97 | 36,801 | 2,320,385 | ||||||||||||
| July 1-31, 2026 | - | - | - | 2,320,385 | ||||||||||||
| Total | 36,801 | $ | 42.97 | 36,801 | 2,320,385 | |||||||||||
| (1) | 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 July 31, 2026, a total of 2,320,385 shares remained available to purchase under this authorization. |
Item 3. Defaults upon Senior Securities
Not Applicable
Item 4. Mine Safety Disclosures
Not Applicable
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Item 5. Other Information
During the three month period ended July
31, 2026, no director or officer, as defined in Rule 16a-1(f),
Item 6. Exhibits
The following exhibits are filed with this report:
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| 32** | Section 1350 Certifications | |
| 101* | The following information from REX American Resources Corporation Quarterly Report on Form 10-Q for the quarter ended July 31, 2026, formatted in iXBRL: (i) Consolidated Balance Sheets, (ii) Consolidated Statements of Operations, (iii) Consolidated Statements of Equity, (iv) Consolidated Statements of Cash Flows and (v) Notes to Consolidated Financial Statements. | |
| 104* | Cover Page Interactive Data File (formatted as Inline XBRL and contained in Exhibit 101) |
* Filed herewith.
** Furnished herewith.
^ Management contract or compensatory plan, contract or arrangement.
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SIGNATURES
Pursuant to the requirements 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 Registrant |
| Signature | Title | Date | ||
| /s/ Zafar A. Rizvi (Zafar A. Rizvi) |
Chief Executive Officer and President (Principal Executive Officer) |
September 3, 2026 | ||
| /s/ Douglas L. Bruggeman (Douglas L. Bruggeman) |
Vice President-Finance, Chief Financial Officer and Treasurer (Principal Financial and Accounting Officer) |
September 3, 2026 |
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