美國

證券交易委員會

華盛頓特區 20549

表格 10-Q

(標記一個)

截至2024年6月30日季度結束 2024年10月31日

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到                    至於                   

委員會檔案編號 001-09097

rex american resources corporation

(依其章程規定的登記名稱)

(937) 276-3931

（申報人的電話號碼，包括區號）

根據《證券法》第12(b)條註冊的證券：

請通過複選標誌指示：（1）在過去的12個月內，是否報告人已提交1934年證券交易法第13或第15(d)款要求提交的所有報告（或註冊人在此期間要求提交此類報告的更短時間內提交了這些報告）；以及（2）是否過去90天裏一直受到這些提交要求的約束。 Yes ☒ 沒有 ☐

通過勾選表示註冊人是否在過去12個月內（或者在註冊人需要提交這些文件的較短期間內）按照S-t規章第405條提交了所有必需的互動數據文件。 Yes ☒ 沒有 ☐

請通過複選標記指示註冊者是否爲大型快速申報人，快速申報人，非快速申報人，較小的報告公司或新興增長型公司。請參見《交易所法》規則120億2中“大型快速申報人”，“快速申報人”，“較小的報告公司”和“新興增長型公司”的定義。

如果一家新興成長型企業，在依據證交所法第13(a)條提供的任何新的或修訂的財務會計標準遵循擴展過渡期的遵循方面選擇不使用該標準，請勾選該方框。 ☐

以勾選符號表示，是否登記人為空殼公司（定義見《證券交易法》第120億2條）。

是 ☐ 否 ☒

截至2024年12月4日的業務結束時，註冊人擁有 17,567,152 的普通股，面值爲每股0.01美元，已發行。

rex american resources 公司及其子公司

指數

頁面

第一部分. 財務資訊

項目 1。 基本報表

rex american resources 公司及其子公司

合併資產負債表

未經審核

附註是這些未經審計的合併財務報表的一個不可分割的部分。

REX 美國資源公司及其子公司

綜合損益表

未經審核

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

REX AMERICAN RESOURCES CORPORATION AND SUBSIDIARIES

Consolidated Statements of Equity

For the Three and Nine Months Ended October 31, 2024 and 2023

Unaudited

(In Thousands)

Continued on the following page

REX AMERICAN RESOURCES CORPORATION AND SUBSIDIARIES

Consolidated Statements of Equity

Unaudited

(In Thousands)

Continued from the previous page

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

REX AMERICAN RESOURCES CORPORATION AND SUBSIDIARIES

Consolidated Statements of Cash Flows

Unaudited

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

REX AMERICAN RESOURCES CORPORATION AND SUBSIDIARIES

NOTES TO UNAUDITED CONSOLIDATED FINANCIAL STATEMENTS

October 31, 2024

Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations

Ethanol and By-Products

At October 31, 2024, 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 October 31, 2024:

Our ethanol operations and the results thereof 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, 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 sale contracts with an appropriate quantity of corn purchase contracts over a given period of time when we can obtain an adequate gross margin resulting from the crush spread inherent in the contracts we have executed. However, the market for future ethanol sales contracts generally lags the spot

market with respect to ethanol price. Consequently, we generally execute fixed price ethanol contracts for no more than four months into the future at any given time and we may lock in our corn or ethanol price without having a corresponding locked in ethanol or corn price for short durations of time. As a result of the relatively short period of time during which our fixed price contracts are fulfilled, 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. 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.

One Earth Energy, LLC Carbon Sequestration and Plant Expansion

Through our affiliate, One Earth Energy, LLC, we are in the developmental stage of a carbon sequestration project near the One Earth Energy ethanol plant in Gibson City, IL. A test well has been drilled to a total depth of approximately 7,100 feet, in which almost 2,000 feet of Mt. Simon Sandstone was encountered, which is the geological formation that is the region’s primary carbon storage resource. Three-dimensional seismic testing has been performed, as well as geological modeling for predicting the movement of injected carbon and the plume area to determine maximum injection pressure, reservoir quality and storage capacity for the potential wells. In October 2022, we applied for a Class VI injection well permit for three wells with the U.S. Environmental Protection Agency (“EPA”), and we continue to provide information to the EPA during the technical review of our application upon request. We currently expect the EPA to prepare a draft permit by the first quarter of 2025 and make a final permit decision by the third quarter of 2025, according to the EPA’s Class VI Permit Tracker Dashboard on their website. We have now secured sufficient subsurface easements for the proposed first injection well to allow for sequestration of all the carbon emissions from the One Earth Energy ethanol plant for a minimum of 15 years. We also need to obtain a county special-use zoning permit for the sequestration site. Last year, we began construction of a facility to capture, dehydrate, and compress carbon dioxide from the One Earth Energy ethanol plant to a state suitable for sequestration. We are nearing the completion of construction of the capture and compression facility.

In October 2023, we submitted an application to the Illinois Commerce Commission (“ICC”) for a certificate of authority under the state’s Carbon Dioxide Transportation and Sequestration Act (the “CO₂ Act”) to build a short pipeline to deliver carbon dioxide from the One Earth Energy ethanol plant to the proposed sequestration site. We also have obtained easements from all of the necessary landowners for the use of their land for the pipeline for the first two wells. On May 26, 2024, however, the Illinois General Assembly passed the Safety and Aid for the Environment in Carbon Capture and Sequestration Act (Senate Bill 1289), which was signed by the governor in July 2024. The new legislation imposes additional safety, environmental and other requirements on obtaining permits and approvals for carbon capture and sequestration facilities in Illinois, including CO₂ pipelines. Further, the new legislation imposes a moratorium on the issuance of new certificates of authority for the construction of CO₂ pipelines until the earlier of the date proposed federal CO₂ pipeline safety standards are finalized by the federal Pipeline and Hazardous Materials Safety Administration (PHMSA) or, subject to certain other conditions, July 1, 2026. As a result of this legislation, the ICC dismissed our application without prejudice, and we will be required to resubmit an application after rules are finalized or subsequent to July 1, 2026.

Although we have made meaningful progress and significant investments in the carbon sequestration project at One Earth Energy, we continue to work with the various government agencies

involved to obtain all required permits and approvals, with no assurance of the ultimate success or timing of the project. Also see the discussion under “Trends and Uncertainties” on page 27 of certain recently proposed legislation that, if enacted, could impact our carbon sequestration project.

We also are concurrently 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, planned for the third quarter of fiscal 2025, we intend to apply for another permit to further increase production to 200 million gallon per year.

We continue to work to identify ways to reduce our carbon intensity (“CI”) score at the One Earth plant with the intention of maximizing the tax credits available under the Inflation Reduction Act, which created a new Clean Fuel Production Credit under 45Z of the Internal Revenue Code (“45Z”), available for calendar years 2025 – 2027, of approximately $0.02 per ethanol gallon per CI point reduction below a 50 CI point threshold to incentivize further increases in plant efficiencies within the industry. The U.S. Department of the Treasury has not yet issued final rules on qualification for 45Z tax credits.

We expect the total cost of these projects to be approximately $165-175 million, which we continue to pay from our available cash. As of October 31, 2024, we have spent $52.9 million life-to-date and are contractually committed to spend an additional $2.4 million toward the carbon sequestration project. If the carbon sequestration project is successful, we believe we will qualify for tax credits under section 45Q of the Internal Revenue Code (“45Q”) and section 45Z of the Internal Revenue Code, as outlined in the Inflation Reduction Act, with 45Z credits being subject to final guidance yet to be issued by the U.S. Department of the Treasury. As of October 31, 2024, we have spent $50.2 million life-to-date and are contractually committed to spend an additional $7.4 million at the One Earth plant toward plant capacity expansion and ongoing efforts to reduce our CI scoring.

Refined Coal

On August 10, 2017, we purchased, through a 95.35% owned subsidiary, for approximately $12.0 million, the entire ownership interest of an entity that owned a refined coal facility. We began operating the refined coal facility immediately after the acquisition. As the plant was no longer eligible to receive federal production tax credits beginning on November 18, 2021, we ceased operations on that date. We began classifying this operation as discontinued operations in the third quarter of fiscal 2021. Over the course of operation, we recognized $58.2 million in tax credits. The federal production tax credits received through operation of this facility remain under IRS audit.

Critical Accounting Policies and Estimates

During the three months ended October 31, 2024, we did not change any of our critical accounting policies as disclosed in our 2023 Annual Report on Form 10-K as filed with the Securities and Exchange Commission on March 29, 2024.

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 2024” means the period February 1, 2024 to January 31, 2025. The Company includes the results of operations of One Earth Energy, LLC (“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.

Results of Operations

Trends and Uncertainties

Renewable Fuel Standard II (“RFS II”), established in October 2010, has been an important factor in the growth of ethanol usage in the United States. In recent years, 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, with the EPA to issue volume obligations in those subsequent years. The EPA also 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 less than 75,000 barrels of oil per day can petition the EPA for a waiver of their obligation to submit renewable identification numbers (“RINs”). The EPA, through consultation with the Department of Energy and the U.S. Department of Agriculture (“USDA”), can grant the refiner a full or partial waiver, or deny the waiver petition. The EPA issued 88 small refinery exemptions (“SREs”) for the 2016-2018 compliance years, undercutting the statutory renewable fuel volumes by a total of 4.3 billion gallons. The EPA did not grant any small refinery waivers for 2019-2022 and has continued that stance in the proposed volumes for 2023-2025. There remain multiple ongoing legal challenges to how the EPA has handled the small refinery waivers. In July 2024, the U.S. Court of Appeals for the District of Columbia Circuit vacated many of the EPA’s 2022 SRE denials. The EPA had denied 105 SREs in 2022. As a result of this Court ruling, the EPA has voluntarily moved to rescind the agency’s 2023 denial of 26 SREs. On November 21, 2024, the EPA reported that 130 SRE petitions were then pending under the RFS, up from 50 as of mid-September. The increase is attributed to submissions from small refineries seeking reconsideration of petitions that were previously denied.

The EPA has issued Renewable Fuel Standard volume obligations for calendar years 2023-2025 for conventional biofuels (which includes corn-based ethanol) of 15.0 billion gallons for each year. Additionally, for 2023, the EPA restored 250 million gallons previously waived.

The Inflation Reduction Act will likely impact our business by creating a new Clean Fuel Production Credit, section 45Z of the Internal Revenue Code (“45Z”), available for the years 2025 to 2027. The Clean Fuel Production Credit is approximately $0.02 per ethanol gallon per CI point reduction below a 50 CI point threshold. The Act also raises the carbon capture tax credit from $50 per metric ton to $85 per metric ton under section 45Q. Taxpayers may elect to be treated as making a payment against tax for 100%

of the value of the 45Q credit (“direct pay”) for the first five years, starting with the year a qualifying carbon sequestration facility is placed in service, but not beyond December 31, 2032. Companies may elect either the 45Q credit or the 45Z credit in periods in which both tax credits are available. Other potential impacts of the Inflation Reduction Act include (a) extension of the biodiesel tax credit, which could support the value of our renewable corn oil, as this co-product serves as a low-carbon feedstock for renewable diesel and biomass based diesel production; (b) creation of new tax credit for sustainable aviation fuel (“SAF”); (c) funding of biofuel refueling infrastructure which could increase the availability of higher level ethanol blended fuel; and (d) provision for production and purchase credits for electric vehicles, which could reduce the amount of internal combustion engines on the road over time, and ultimately reduce the demand for gasoline, diesel fuels and ethanol.

In April 2024, the U.S Department of the Treasury and the IRS released updated guidance which included an updated GREET (Greenhouse Gases, Regulated Emissions, and Energy use in Technologies) lifecycle model for the section 40B SAF tax credit. This model provides a pathway for U.S. corn-based ethanol to be considered a qualifying feedstock for SAF if certain measures are taken to lower carbon intensity of production. GREET is used as a model to calculate greenhouse gas (“GHG”) reductions. The GREET model aims to provide a comprehensive assessment of the environmental impact of aviation fuels focusing on reducing GHG emissions through the entire lifecycle of the fuel, including through carbon capture and certain climate-smart agricultural (“CSA) practices. CSA practices for corn production must include no-till farming, planting cover crops and using enhanced efficiency nitrogen fertilizers. The section 40B credit expires on December 31, 2024 and is being replaced by the 45Z tax credit. A new 45Z-GREET model has not yet been developed by the U.S. Department of the Treasury, but will likely require further modeling, data assumptions, and verification.

Illinois Senate Bill 3968, which was recently introduced into the Illinois Senate and assigned to the Executive Senate Committee would, if eventually enacted, ban carbon sequestration projects if they overlie, underlie, or pass through a sole-source aquifer, including the aquifer’s upstream areas that are part of the aquifer’s project review area, as identified by the U.S. EPA. On November 14, 2024, the Executive Senate Committee paused the bill until they can gather additional information. The first well for our proposed carbon sequestration project is located inside, at the edge of the Mahomet Sole Source Aquifer Project Review Area, within the Sangamon River near Fisher Upstream Area. It is approximately five miles north of the Sangamon River and nearly six miles from the mapped boundary of the Mahomet Aquifer, which has been designated as a sole source or principal aquifer by the U.S. EPA. We believe our second and third sequestration well sites are outside the Mahomet Sole Source Aquifer Project Review Area. The Company is closely monitoring this bill and any impact it would have on our project.

Additionally, see “One Earth Energy, LLC Carbon Sequestration and Plant Expansion” above for a discussion of certain other uncertainties associated with our Illinois carbon sequestration and plant expansion projects.

The trends and uncertainties mentioned above could impact our future operating results in both positive and negative ways.

Comparison of Three and Nine Months Ended October 31, 2024 and 2023

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

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

The following table summarizes selected operating data:

Net sales and revenue in the quarter ended October 31, 2024 decreased 21% compared to the prior year’s third quarter. Net sales and revenue in the first nine months ended October 31, 2024 decreased approximately 25% compared to the first nine months of 2023.

Ethanol revenue decreased 19% in the third quarter of fiscal year 2024 compared to the third quarter of fiscal year 2023 as the average selling price of ethanol at our consolidated plants decreased 21% during the third quarter of fiscal year 2024 compared to the prior year comparable period, partially offset by a 3% increase in gallons of ethanol sold. Ethanol revenue decreased 25% in the first nine months of fiscal year 2024 compared to the first nine months of fiscal year 2023, driven by a 25% decrease in selling price while gallons sold did not change significantly. The decrease in the ethanol selling price resulted primarily from a decrease in corn prices as the market price for ethanol often correlates with the market price for corn.

Dried distillers grains revenue decreased 28% in the third quarter of fiscal year 2024 compared to the third quarter of fiscal year 2023 as the average price per ton sold decreased 25%, coupled with a 5% decrease in tons sold. Dried distillers grains revenue decreased 27% in the first nine months of fiscal year 2024 compared to the first nine months of fiscal year 2023, driven by a 25% decrease in the average selling price, along with a 3% decrease in the tons sold. The decrease in the dried distillers grains selling price resulted primarily from a decrease in corn prices as dried distillers grains prices often correlate with corn pricing.

Distillers corn oil revenue decreased approximately 31% in the third quarter of fiscal year 2024 compared to the third quarter of fiscal year 2023 as the average price per pound sold decreased 28%, along with a 3% decrease in pounds sold. Distillers corn oil revenue decreased 27% in the first nine months of 2024 compared to the first nine months of 2023 as the average price per pound decreased 27%, along with

a 1% decrease in pounds sold. The decrease in the distillers corn oil selling price resulted primarily from fluctuations in demand with the renewable biodiesel market and is often tied to the price of soybean oil.

Modified distillers grains revenue did not change in the third quarter of fiscal year 2024 compared to the third quarter of fiscal year 2023 due to a 36% increase in the tons sold, offset by a decrease in the average selling price per ton sold of 27%. Modified distillers grains revenue decreased 9% in the first nine months of fiscal year 2024 compared to the first nine months of fiscal year 2023 due to a 34% decrease in the average selling price per ton sold, offset by a 39% increase in tons sold during the same period. The decrease in the modified distillers grains selling price resulted primarily from a decrease in corn prices as prices tend to move in the same direction. Our consolidated plants’ decisions to sell modified or dried distillers grains fluctuate from time to time based upon market conditions.

Gains on derivative financial instruments, included in net sales and revenue, were approximately $0.3 million in the three-month period ended October 31, 2024, compared to no gain or loss on derivative financial instruments during the three-month period ended October 31, 2023. Gains on derivative financial instruments, included in net sales and revenue, were approximately $0.7 million in the nine-month period ended October 31, 2024, compared to losses of $29,000 on derivative financial instruments during the nine-month period ended October 31, 2023. These gains and losses are related to our risk management activities and were impacted by the price movements of ethanol.

Cost of sales decreased approximately 26% in the quarter ended October 31, 2024, compared to the prior year third quarter. Corn accounted for approximately 76% ($102.6 million) of our cost of sales during the third quarter of fiscal year 2024 compared to approximately 80% ($145.2 million) during the third quarter of fiscal year 2023. Natural gas accounted for approximately 3% of our cost of sales during the third quarter of fiscal year 2024 ($4.6 million) and the third quarter of fiscal year 2023 ($6.2 million). Cost of sales decreased approximately 29% in the nine-months ended October 31, 2024, compared to the prior year comparable period. Corn accounted for approximately 76% ($312.2 million) of our cost of sales during the first nine months of fiscal year 2024 compared to approximately 81% ($467.0 million) during the first nine months of fiscal year 2023. Natural gas accounted for approximately 4% of our cost of sales during the nine months ended October 31, 2024 ($15.6 million) and during the first nine months of fiscal year 2023 ($23.3 million). The cost of corn and natural gas decreased primarily due to lower pricing for both during the three and nine months ended October 31, 2024.

As a result of the foregoing, gross profit for the third quarter of fiscal year 2024 increased approximately $0.4 million compared to the prior year’s third quarter. Gross profit for the first nine months of fiscal year 2024 increased approximately $6.1 million compared to the first nine months of fiscal year 2023.

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 were approximately $8.4 million for the third quarter of fiscal year 2024, compared to approximately $7.6 million of expenses for the third quarter of fiscal year 2023. The increase from the prior year third quarter are due primarily to an increase in railcar lease expense and an increase in donations of emergency equipment to local first responders related to carbon capture. SG&A expenses were approximately $21.0 million for the first nine months of fiscal year 2024, compared to approximately $22.0 million for the first nine months of fiscal year 2023. The decrease compared to the prior year nine-month period are primarily related to restricted stock awards granted to certain executive officers in the second quarter of 2023, which were expensed upon issuance, offset partially by the increase in performance bonus expense as a result of higher net income in 2024.

During the third quarter of fiscal year 2024, we recognized income from our equity investment in Big River of approximately $3.6 million compared to income of approximately $4.7 million for the third quarter of fiscal year 2023. During the first nine months of fiscal year 2024, we recognized income from our equity investment in Big River of approximately $7.1 million compared to income of approximately $9.3 million during the first nine months of fiscal year 2023. Our investment in Big River, which has interests in four ethanol production plants, represents an effective ownership of approximately 38.5 million gallons of ethanol shipped in the trailing twelve months ended October 31, 2024. 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 $4.6 million for the third quarter of fiscal year 2024 versus approximately $4.9 million for the third quarter of fiscal year 2023. Interest and other income was approximately $15.0 million for the first nine months of 2024 versus approximately $10.9 million for the first nine months of fiscal year 2023. One of our consolidated ethanol plants recognized $1.2 million in patronage income from an investment in a cooperative in the first quarter of 2024. During 2023, the Company’s consolidated plants received COVID-19 relief grants from the USDA of approximately $0.9 million and $1.0 million for the three- and nine-month periods ended October 31, 2023. The remaining change between the year-to-date periods related to increased interest income in the current year based upon higher balances and yields on our excess cash and short-term investments in fiscal year 2024, compared to 2023.

As a result of the foregoing, income before income taxes was approximately $39.5 million and $41.3 million for the third quarters of fiscal year 2024 and 2023, respectively. Income before income taxes was approximately $75.0 million and $66.0 million for the first nine months of fiscal year 2024 and 2023, 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 $9.4 million and $9.6 million for the three months ended October 31, 2024 and 2023, respectively. Our income tax provision was approximately $17.6 million and $15.4 million for the first nine months of fiscal year 2024 and 2023, respectively.

As a result of the foregoing, net income was approximately $30.1 for the third quarter of fiscal year 2024 compared to approximately $31.6 million for the third quarter of fiscal year 2023. Net income was approximately $57.4 million for the first nine months of fiscal year 2024 compared to approximately $50.6 million for the first nine months of fiscal year 2023.

Net income attributable to noncontrolling interests was approximately $5.6 million for the third quarters of fiscal year 2024 and 2023. Net income attributable to noncontrolling interests was approximately $10.3 million for the first nine months of fiscal years 2024 and 2023. 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 third quarter of fiscal year 2024 was approximately $24.5 million, compared to net income attributable to REX common shareholders of approximately $26.1 million for the third quarter of fiscal year 2023. Net income attributable to REX common shareholders from the first nine months of fiscal year 2024 was approximately $47.1 million, compared to net income attributable to REX common shareholders of approximately $40.4 million for the first nine months of fiscal year 2023.

Liquidity and Capital Resources

Net cash provided by operating activities was approximately $39.1 million for the first nine months of fiscal year 2024, compared to net cash provided by operating activities of approximately $65.5 million for the first nine months of fiscal year 2023. For the first nine months of fiscal year 2024, cash was provided by net income of approximately $57.4 million, adjusted upward for non-cash items of approximately $20.3 million, which consisted of depreciation, amortization of operating lease right-of-use assets, 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. We received dividends from Big River of approximately $3.0 million. A decrease in the balance of accounts receivable provided cash of approximately $0.9 million, primarily a result of the timing of products shipped and the receipt of customer payments at One Earth and NuGen. Inventories increased over the first nine months of fiscal year 2024, using cash of approximately $2.1 million. An increase in the balance of other assets of approximately $12.6 million primarily relates to prepayments on certain executed lease agreements, offset by changes in the carrying value of forward purchase contracts and commodity futures positions recorded at fair value, decreases to spare parts inventory and decreases to prepaid insurance balances. A decrease in the balance of refundable income taxes of approximately $0.2 million primarily relates to the accrual of the federal taxes currently payable and the timing of estimated tax payments for the first nine months of 2024. 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. A decrease in the balance of accounts payable used cash of approximately $21.6 million, which was primarily a result of the timing of inventory receipts and vendor payments. A decrease in the balance of other liabilities used cash of approximately $6.2 million, which was primarily caused by the reduction in the lease liability of $4.0 million from payments made during the year. Additionally, a decrease in accrued payroll and accrued utility liabilities used cash of approximately $0.6 million and $1.3 million, respectively. The decrease in the accrued payroll is primarily related to the payment of the 2023 incentive bonuses, offset partially by the accrual of the 2024 incentive bonuses to be paid in 2025. Other offsetting fluctuations within other liabilities were insignificant.

Net cash provided by operating activities was approximately $65.5 million for the first nine months of fiscal year 2023. For the first nine months of fiscal year 2023, cash was provided by net income of approximately $50.6 million, adjusted for non-cash items of approximately $16.3 million, which consisted of depreciation, amortization of operating lease right-of-use assets, 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. We received dividends from Big River of approximately $5.5 million. An increase in the balance of accounts receivable used cash of approximately $5.0 million, primarily a result of the timing of products shipped and the receipt of customer payments at One Earth and NuGen. Inventories decreased over the first nine months of fiscal year 2023, providing cash of $11.2 million. An increase in the balance of other assets of approximately $1.3 million primarily relates to changes in the carrying value of forward purchase contracts and commodity futures positions recorded at fair value. An increase in the balance of refundable income taxes of approximately $1.5 million primarily relates to overpayment of taxes currently payable for the previous fiscal year and quarterly estimated tax payments. 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. A decrease in the balance of accounts payable used cash of approximately $5.6 million, which was primarily a result of the timing of inventory receipts and vendor payments. A decrease in the balance of other liabilities used cash of approximately $4.8 million.

At October 31, 2024, working capital was approximately $392.5 million, compared to $385.8 million at January 31, 2024. The ratio of current assets to current liabilities was 9.9 to 1 at October 31, 2024 and 6.8 to 1 at January 31, 2024.

Cash of approximately $37.6 million was provided by investing activities for the first nine months of fiscal year 2024, compared to cash used in investing activities of approximately $63.3 million during the first nine months of fiscal year 2023. During the first nine months of fiscal year 2024, the Company had capital expenditures of approximately $55.4 million, primarily for various capital projects at our consolidated ethanol plants, including $24.5 million for expansion and CI scoring reduction projects at the One Earth facility and $22.4 million for the carbon sequestration project. During the first nine months of fiscal year 2024, we purchased short-term U.S. Treasury Bills of approximately $210.3 million, while U.S. Treasury Bills of approximately $303.0 million matured. The U.S Treasury Bills had maturities of less than one year and we classified them as short-term investments. Depending on the investment options available, we may elect to retain the funds, or a portion thereof, in cash, short-term investments or long-term investments.

Cash of approximately $63.3 million was used in investing activities for the first nine months of fiscal year 2023. During the first nine months of fiscal year 2023, we had capital expenditures of approximately $22.4 million, primarily for various capital projects at our consolidated ethanol plants, including $7.7 million for expansion and CI scoring reduction projects at the One Earth facility and $8.0 million for the carbon sequestration project. During the first nine months of fiscal year 2023, we purchased U.S. Treasury Bills of approximately $378.4 million. During the first nine months of fiscal year 2023 U.S. Treasury Bills of approximately $337.5 million matured. The U.S Treasury Bills had maturities of less than one year and we classified them as short-term investments.

Cash of approximately $1.9 million was used in financing activities for the first nine months of fiscal year 2024 for payments to noncontrolling interests holders, compared to approximately $0.7 million for the first nine months of fiscal year 2023.

We are investigating various uses for our excess cash and short-term investments. We expect total capital expenditures related to the construction at the One Earth facilities to approximate $165 million to $175 million, inclusive of the carbon sequestration project and plant capacity expansion and ongoing efforts to reduce CI scoring, which we currently plan to pay from our available cash. As of October 31, 2024, we have spent $52.9 million since inception and are contractually committed to spend an additional $2.4 million toward the carbon sequestration project. As of October 31, 2024, we have spent $50.2 million since inception and are contractually committed to spend an additional $7.4 million toward plant capacity expansion and CI scoring reduction efforts. For all projects, we plan to spend $25 million to $35 million during the remainder of fiscal year 2024.

We have a stock buyback program with 876,786 shares remaining authorized at October 31, 2024. We typically repurchase our common stock when our stock price is trading at a price we deem to be a discount to the underlying value of our net assets. We continue to seek investment opportunities, including ethanol and/or energy related, carbon sequestration related, agricultural or other ventures, we believe meet our investment criteria.

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 effect of pandemics such as COVID-19 on the Company’s business operations, including impacts on supplies, demand, personnel and other factors, the impact of legislative and regulatory changes, the price volatility and availability of corn, distillers grains, ethanol, distillers corn oil, gasoline and natural gas, commodity market risk, ethanol plants operating efficiently and according to forecasts and projections, logistical interruptions, success in permitting and developing the planned carbon sequestration facility near the One Earth Energy ethanol plant, changes in the international, national or regional economies, the impact of inflation, the ability to attract employees, weather, results of income tax audits, changes in income tax laws or regulations, the impact of U.S. foreign trade policy, changes in foreign currency exchange rates and the effects of terrorism or acts of war. 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, 2024 (File No. 001-09097).

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 October 31, 2024 is as follows, assuming normal operating capacity (amounts in thousands):

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.

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, 2024.

Item 2. Unregistered Sales of Equity Securities and Use of Proceeds

On August 31, 2021, our Board of Directors increased our share repurchase authorization by an additional 1,500,000 shares (split-adjusted). At October 31, 2024, a total of 876,786 shares remained available to purchase under this authorization.

There were no share repurchases by the Company in the third quarter of fiscal year 2024.

Item 3. Defaults upon Senior Securities

Not Applicable

Item 4. Mine Safety Disclosures

Not Applicable

Item 5. Other Information

Not Applicable

Item 6. Exhibits

The following exhibits are filed with this report:

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.