REX AMERICAN RESOURCES Corp - Quarter Report: 2019 October (Form 10-Q)

UNITED STATES
SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D.C. 20549

FORM 10-Q

(Mark One)

Commission File Number 001-09097

REX AMERICAN RESOURCES CORPORATION

(Exact name of registrant as specified in its charter)

(937) 276-3931

(Registrant’s telephone number, including area code)

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

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

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).                    Yes x  No o

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.

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. o

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).

Yes o  No x

At the close of business on December 4, 2019 the registrant had 6,293,322 shares of Common Stock, par value $.01 per share, outstanding.

REX AMERICAN RESOURCES CORPORATION AND SUBSIDIARIES

INDEX

PART I. FINANCIAL INFORMATION

Item 1. Financial Statements

REX AMERICAN RESOURCES CORPORATION AND SUBSIDIARIES

Consolidated Condensed Balance Sheets

Unaudited

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

REX AMERICAN RESOURCES CORPORATION AND SUBSIDIARIES

Consolidated Condensed Statements of Operations

Unaudited

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

REX AMERICAN RESOURCES CORPORATION AND SUBSIDIARIES

Consolidated Condensed Statements of Equity

For the Three and Nine Months Ended October 31, 2019 and 2018

Unaudited

(In Thousands)

Continued on the following page

REX AMERICAN RESOURCES CORPORATION AND SUBSIDIARIES

Consolidated Condensed Statements of Equity

For the Three and Nine Months Ended October 31, 2019 and 2018

Unaudited

(In Thousands)

Continued from the previous page

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

REX AMERICAN RESOURCES CORPORATION AND SUBSIDIARIES

Consolidated Condensed Statements of Cash Flows

Unaudited

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

REX AMERICAN RESOURCES CORPORATION AND SUBSIDIARIES

NOTES TO UNAUDITED CONSOLIDATED CONDENSED FINANCIAL STATEMENTS

October 31, 2019

Note 1.  Consolidated Condensed Financial Statements

References to the Company – References to “REX” or the “Company” in the consolidated condensed financial statements and in these notes to the consolidated condensed financial statements refer to REX American Resources Corporation, a Delaware corporation, and its majority and wholly owned subsidiaries.

The consolidated condensed 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, 2019 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, 2019 (fiscal year 2018). It is suggested that these unaudited consolidated condensed financial statements 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, 2019. 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 condensed 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 four majority owned subsidiaries. The Company includes the results of operations of One Earth Energy, LLC (“One Earth”) in its Consolidated Condensed Statements of Operations on a delayed basis of one month as One Earth has a fiscal year end of December 31.

Nature of Operations –The Company has two reportable segments: i) ethanol and by-products; and ii) refined coal. Within the ethanol and by-products segment, the Company has equity investments in three ethanol limited liability companies, two of which are majority ownership interests. Within the refined coal segment, the Company has a majority equity interest in one refined coal limited liability company.

Note 2.  Accounting Policies

The interim consolidated condensed 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 2018 Annual Report on Form 10-K and the adoption of new accounting standards described at the end of this footnote. 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.

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.

Revenue Recognition

For ethanol and by-products segment sales, the Company recognizes sales of ethanol, distillers grains and non-food grade 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. For refined coal segment sales, the Company recognizes sales of refined coal when obligations under the term of the contract with its customer are satisfied; this occurs when title and control of the product transfers to its customer, generally upon the coal leaving the refined coal plant. Refined coal sales are recorded net of the cost of coal as the Company purchases the coal feedstock from the customer to which the processed refined coal is sold.

Cost of Sales

Cost of sales includes depreciation, costs of raw materials, inbound freight charges, purchasing and receiving costs, inspection costs, other distribution expenses, warehousing costs, plant management, certain compensations costs and general facility overhead charges.

Selling, General and Administrative (“SG&A”) Expenses

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

Financial Instruments

Certain of the forward grain purchase and ethanol, distillers grains and non-food grade corn oil sale contracts are accounted for under the “normal purchases and normal sales” scope exemption of Accounting Standards Codification (“ASC”) 815, “Derivatives and Hedging” (“ASC 815”) because these arrangements are for purchases of grain that will be delivered in quantities expected to be used by the Company and sales of ethanol, distillers grains and non-food grade corn oil quantities expected to be produced 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) to manage a portion of the risk associated with changes in commodity prices, primarily related to corn. 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 use hedge accounting.

Income Taxes

Historically, the Company recorded its interim tax provision or benefit for income taxes including the three and nine months ended October 31, 2018, by applying an estimate of the annual effective tax rate for the full fiscal year to “ordinary” income or loss (pre-tax income or loss excluding unusual or infrequently occurring discrete items) for the reporting period. The Company determined that since small changes in estimated “ordinary” income would result in significant changes in the estimated annual effective tax rate, the historical method would not provide a reliable estimate for the three and nine months ended October 31, 2019. Thus, the Company used a discrete effective tax rate method to calculate the provision or benefit for income taxes for the three and nine months ended October 31, 2019.

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 evidence, it is more likely than not that some or all of the deferred tax assets will not be realized. The Company paid no income taxes nor received refunds of income taxes during the nine months ended October 31, 2019. The Company paid income taxes of approximately $0.9 million during the nine months ended October 31, 2018. The Company received no refunds of income taxes during the nine months ended October 31, 2018.

As of October 31, 2019 and January 31, 2019, total unrecognized tax benefits were approximately $8.6 million and approximately $8.8 million, respectively. Accrued penalties and interest were approximately $0.5 million and approximately $0.4 million at October 31, 2019 and January 31, 2019, respectively. If the Company were to prevail on all unrecognized tax benefits recorded, the provision for income taxes would be reduced by approximately $8.2 million. In addition, the impact of penalties and interest would also benefit the effective tax rate. Interest and penalties associated with unrecognized tax benefits are recorded within income tax expense. On a quarterly basis, the Company accrues for the effects of open uncertain tax positions and the related potential penalties and interest.

Inventories

Inventories are carried at the lower of cost or market on a first-in, first-out basis. Inventory includes direct production costs and certain overhead costs such as depreciation, property taxes and utilities associated with producing ethanol and related by-products and refined coal. Inventory is permanently written down for instances when cost exceeds estimated net realizable value; such write-downs are based primarily upon commodity prices as the market value of inventory is often dependent upon changes in commodity prices. There was no significant permanent write-down of inventory at October 31, 2019 and January 31, 2019. Fluctuations in the write-down of inventory generally relate to the levels and

composition of such inventory at a given point in time. The components of inventory are as follows as of the dates presented (amounts in thousands):

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 5 to 40 years for buildings and improvements, and 2 to 20 years for fixtures and equipment.

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. There were no impairment charges in the first nine months of fiscal years 2019 or 2018.

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 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 20% ownership interest using the equity method of accounting when the factors discussed in ASC 323, “Investments-Equity Method and Joint Ventures” are met. The excess of the carrying value over the underlying equity in the net assets of equity method investees is allocated to specific assets and liabilities. Investments in businesses that the Company does not control but for which it has the ability to exercise significant influence over operating and financial matters are accounted for using the equity method. The Company accounts for its investment in Big River Resources, LLC (“Big River”) using the equity method of accounting and includes the results on a delayed basis of one month as Big River has a fiscal year end of December 31.

The Company periodically evaluates its investments for impairment due to declines in market value considered to be other than temporary. Such impairment evaluations include 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 Condensed Statements of Operations and a new cost basis in the investment is established.

Short-term investments are considered held to maturity, and, therefore are carried at amortized historical cost.

Comprehensive Income

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

Accounting Changes and Recently Issued Accounting Standards

Effective February 1, 2019, the Company adopted the amended guidance in Accounting Standards Codification “ASC” Topic 842 “Leases” and all related amendments (“ASC 842”), which requires virtually all leases be recognized by lessees on their balance sheet as right-of-use assets and corresponding lease liabilities. The adoption of ASC 842 had a material impact on the Company’s Consolidated Condensed Balance Sheet as total assets and total liabilities increased by approximately $20.9 million upon adoption. The adoption of ASC 842 did not have a material impact on the Company’s Consolidated Condensed Statement of Operations for the three and nine months ended October 31, 2019. See Note 4 for a further discussion of the Company’s adoption of this amended guidance.

In August 2018, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) 2018-13, “Changes to Disclosure Requirements for Fair Value Measurements”, which improves the effectiveness of recurring and non-recurring fair value measurements disclosures. This standard removes, modifies and adds certain disclosure requirements and is effective for the Company beginning February 1, 2020. The Company has not determined the effect of this standard on its consolidated financial statements and related disclosures.

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 used to transport the products. Revenue is measured as the amount of consideration expected to be received in exchange for transferring goods. Sales, value added and other taxes the Company collects concurrent with revenue producing activities are excluded from net sales and revenue.

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

See Note 15 for disaggregation of net sales and revenue by operating segment and by product.

Note 4.  Leases

The Company used the optional transition method in adopting ASC 842, which resulted in applying

ASC 842 at the date of adoption (February 1, 2019). Thus, comparative information has not been restated and continues to be reported under accounting standards in effect for those periods.

ASC 842 provides for three practical expedients, which the Company elected as a package. Pursuant to this package, the Company did not reassess: i) whether any expired or existing contracts are or contain leases; ii) the lease classification for any expired or existing leases that were previously classified as operating leases; or iii) the initial direct costs for any existing leases.

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

At October 31, 2019, the Company has 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 exercise of any lease renewal is at the Company’s sole discretion. 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. The components of lease expense, classified as SG&A expenses on the Consolidated Condensed Statement of Operations are as follows:

The following table is a summary of future minimum rentals on such leases at October 31, 2019 (amounts in thousands):

At October 31, 2019, the weighted average remaining lease term is 3.7 years and the weighted average discount rate is 5.46% for the above leases.

At January 31, 2019, the Company had operating lease agreements (pursuant to ASC 840, “Leases”), as lessee, for railcars and other equipment. At January 31, 2019, future minimum annual rentals on such leases were as follows (amounts in thousands):

Note 5.  Fair Value

The Company applies ASC 820, “Fair Value Measurements and Disclosures” (“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 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 basis at October 31, 2019 are summarized below (amounts in thousands):

Financial assets and liabilities measured at fair value on a recurring basis at January 31, 2019 are summarized below (amounts in thousands):

(1) The investment in cooperative is included in “Other assets” on the accompanying Consolidated Condensed Balance Sheets.

(2) The forward purchase contract asset and commodity futures asset are included in “Prepaid expenses and other current assets” on the accompanying Consolidated Condensed Balance Sheets.

(3) The forward purchase contract liability is included in “Accrued expenses and other current liabilities” on the accompanying Consolidated Condensed Balance Sheets.

(4) The commodity futures liability is included in “Accrued expenses and other current liabilities” on the accompanying Consolidated Condensed Balance Sheets.

The Company determined the fair value of the investment in cooperative by using a discounted cash flow analysis on the expected cash flows. Inputs used in the analysis include the face value of the allocated equity amount, the projected term for repayment based upon a historical trend and a risk adjusted discount rate based on the expected compensation participants would demand because of the uncertainty of the future cash flows. The inherent risk and uncertainty associated with unobservable inputs could have a significant effect on the actual fair value of the investment.

There were no assets measured at fair value on a non-recurring basis at October 31, 2019 or January 31, 2019.

Note 6.  Property and Equipment

The components of property and equipment are as follows for the periods presented (amounts in thousands):

Note 7.  Other Assets

The components of other assets are as follows for the periods presented (amounts in thousands):

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):

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 and forward purchase (corn and natural gas) and sale (ethanol, distillers grains and non-food grade 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 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 Condensed Balance Sheets in which the fair values are reflected (in thousands):

(1) Commodity futures assets are included in prepaid expenses and other current assets. These contracts are short/sell positions for approximately 3.6 million bushels of corn, long/buy positions for approximately 2.7 million bushels of corn and short/sell positions for approximately 2.1 million gallons of ethanol at October 31, 2019. These contracts are short/sell positions for approximately 2.0 million bushels of corn at January 31, 2019. Commodity futures liabilities are included in accrued expenses and other current liabilities. These contracts are short/sell positions for approximately 2.6 million

bushels of corn.

(2) Forward purchase contracts assets are included in prepaid expenses and other current assets. These contracts are for purchases of approximately 0.8 million bushels of corn at October 31, 2019. Forward purchase contracts liabilities are included in accrued expenses and other current liabilities. These contracts are for purchases of approximately 1.3 million bushels of corn at January 31, 2019.

As of October 31, 2019, and January 31, 2019, all of the derivative financial instruments held by the Company were subject to enforceable master netting arrangements. The Company’s accounting policy is to offset positions and amounts owed or owing with the same counterparty. As of October 31, 2019, and January 31, 2019, the gross positions of the enforceable master netting agreements are not significantly different from the net positions presented in the table above. Depending on the amount of an unrealized loss on a derivative contract held by the Company, the counterparty may require collateral to secure the Company’s derivative contract position. The Company was required to maintain collateral in the amount of approximately $523,000 and approximately $281,000 to secure the Company’s derivative position at October 31, 2019 and January 31, 2019, respectively.

See Note 5 which contains fair value information related to derivative financial instruments.

Gains on the Company’s derivative financial instruments of approximately $248,000 and approximately $2,432,000 for the third quarter of fiscal years 2019 and 2018, respectively, were included in cost of sales on the Consolidated Condensed Statements of Operations. Gains on the Company’s derivative financial instruments of approximately $1,478,000 and approximately $2,273,000 for the first nine months of fiscal years 2019 and 2018, respectively, were included in cost of sales on the Consolidated Condensed Statements of Operations.

Note 10.  Investments

The following table summarizes the Company’s equity method investment at October 31, 2019 and January 31, 2019 (dollars in thousands):

Undistributed earnings of the Company’s equity method investee totaled approximately $11.4 million and approximately $12.0 million at October 31, 2019 and January 31, 2019, respectively. The Company received dividends from its equity method investee of approximately $1.0 million and approximately $3.0 million during the first nine months of fiscal years 2019 and 2018, respectively.

Summarized financial information for the Company’s equity method investee is presented in the following table for the periods presented (amounts in thousands):

The following table summarizes the Company’s held-to-maturity security at January 31, 2019 (amounts in thousands):

As of January 31, 2019, the contractual maturity of this investment was less than one year and the yield to maturity rate was 2.29%.

Note 11.  Employee Benefits

The Company maintains the REX 2015 Incentive Plan, approved by its shareholders, which reserves a total of 550,000 shares of common stock for issuance pursuant to its terms. The plan provides for the granting of shares of stock, including options to purchase shares of common stock, stock appreciation rights tied to the value of common stock, restricted stock, and restricted stock unit awards to eligible employees, non-employee directors and consultants. Since plan inception, the Company has only granted restricted stock awards. The Company measures share-based compensation grants at fair value on the grant date, adjusted for estimated forfeitures. The Company records noncash compensation expense related to liability and equity awards in its consolidated financial statements over the requisite service period on a straight-line basis. At October 31, 2019, 479,988 shares remain available for issuance under the Plan. As a component of their compensation, restricted stock has been granted to directors at the closing market price of REX common stock on the grant date. In addition, one third 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 15^th, or the next business day if June 15^th is not a business day, for all grants of restricted stock.

At October 31, 2019 and January 31, 2019, unrecognized compensation cost related to nonvested restricted stock was approximately $259,000 and $200,000, respectively. The following tables summarize

non-vested restricted stock award activity for the periods presented:

The above tables include 24,219 and 34,148 non-vested shares at October 31, 2019 and 2018, respectively, which are included in the number of weighted average shares outstanding used to determine basic and diluted earnings per share attributable to REX common shareholders. Such shares are treated, for accounting purposes, as being fully vested at the grant date as they were granted to recipients who were retirement eligible at the time of grant.

Note 12.  Income Taxes

Historically, the Company recorded its interim tax provision or benefit for income taxes including the three and nine months ended October 31, 2018, by applying an estimate of the annual effective tax rate for the full fiscal year to “ordinary” income or loss (pre-tax income or loss excluding unusual or infrequently occurring discrete items) for the reporting period. The Company determined that since small changes in estimated “ordinary” income would result in significant changes in the estimated annual effective tax rate, the historical method would not provide a reliable estimate for the three and nine months

ended October 31, 2019. Thus, the Company used a discrete effective tax rate method to calculate the provision or benefit for income taxes for the three and nine months ended October 31, 2019.

The Company’s tax benefit was approximately 65.9% and approximately 266.7% for the three months ended October 31, 2019 and 2018, respectively. The Company’s tax benefit was approximately 234.7% and approximately 112.8% for the nine months ended October 31, 2019 and 2018, respectively. The fluctuation in the rate results primarily from the production tax credits the Company expects to receive associated with its refined coal segment relative to pre-tax income or loss. Through its refined coal operation, the Company earns production tax credits pursuant to IRC Section 45. The credits can be used to reduce future income tax liabilities for up to 20 years.

The Company files a U.S. federal income tax return and various state income tax returns. 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. A reconciliation of the beginning and ending amount of unrecognized tax benefits, including interest and penalties, is as follows (amounts in thousands):

Note 13.  Commitments and Contingencies

The Company is involved in various legal actions arising in the normal course of business. After taking into consideration legal counsels’ evaluations of such actions, management is of the opinion that their outcome will not have a material adverse effect on the Company’s Consolidated Condensed Financial Statements.

One Earth and NuGen have combined forward purchase contracts for approximately 4.4 million bushels of corn, the principal raw material for their ethanol plants. They expect to take delivery of the grain through January 2020.

One Earth and NuGen have combined forward purchase contracts for approximately 1,067,000 MmBtu (million british thermal units) of natural gas. They expect to take delivery of the natural gas through February 2020.

One Earth and NuGen have combined sales commitments for approximately 18.9 million gallons of ethanol, approximately 48,500 tons of distillers grains and approximately 6.1 million pounds of non-food grade corn oil. They expect to deliver a majority of the ethanol, distillers grains and non-food grade corn oil through December 2019.

The refined coal entity has various agreements (site license, operating agreements, etc.) containing payment terms based upon production of refined coal under which the Company is required to pay various fees. These fees totaled approximately $0.9 million and approximately $2.6 million in the third quarter of fiscal year 2019 and 2018, respectively. Such fees totaled approximately $3.6 million and approximately $7.7 million for the nine months ended October 31, 2019 and 2018, respectively.

Note 14.  Related-Party Transactions

During the third quarters of fiscal years 2019 and 2018, One Earth and NuGen purchased approximately $58.5 million and approximately $47.3 million, respectively, of corn from minority equity investors and board members of those subsidiaries. Such purchases totaled approximately $148.7 million and approximately $138.6 million for the nine months ended October 31, 2019 and 2018, respectively. The Company had amounts payable to related parties for corn purchases of approximately $0.1 million and approximately $1.9 million at October 31, 2019 and January 31, 2019, respectively.

One Earth terminated its agreement with its corn origination agent at the end of the third quarter of fiscal year 2019. In connection with this, the Company had amounts receivable from related parties of approximately $6.7 million at October 31, 2019.

During the third quarters of fiscal years 2019 and 2018, the Company recognized commission income of approximately $0.2 million and expense of approximately $0.4 million, respectively, payable to the minority investor in the refined coal entity. During the first nine months of fiscal years 2019 and 2018, the Company recognized commission income of approximately $0.6 million and expense of approximately $0.7 million, respectively. The commission income or expense is associated with the refined coal acquisition. The Company had accrued liabilities and accounts payable related to the commission income or expense of approximately $0.7 million and approximately $1.6 million at October 31, 2019 and January 31, 2019, respectively.

Note 15.  Segment Reporting

The Company has two reportable segments: i) ethanol and by-products; and ii) refined coal. The Company evaluates the performance of each reportable segment based on segment profit. The following tables summarize segment and other results and assets (amounts in thousands):

¹ The Company records sales in the refined coal segment net of the cost of coal as the Company purchases the coal feedstock from the customer to which refined coal is sold.

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

Ethanol and By-Products

At October 31, 2019, investments in our ethanol business include equity investments in three ethanol limited liability companies, two of which we have a majority ownership interest in. The following table is a summary of ethanol gallons shipped at our plants:

Our ethanol operations and the results thereof are highly dependent on commodity prices, especially prices for corn, ethanol, distillers grains, non-food grade 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 and foreign trade. Because the market price of ethanol is not always directly related to corn prices (for example, crude and other energy prices, the export market demand for ethanol and the results of federal policy decisions and trade negotiations can impact ethanol prices), at times ethanol prices may not

follow movements in corn prices and, in an environment of higher corn prices or lower ethanol 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 2.8 gallons of denatured ethanol for each bushel of grain processed in the production cycle. We refer to the actual gallons of denatured ethanol produced per bushel of grain processed as the realized yield. We refer to the difference between the price per gallon of ethanol and the price per bushel of grain (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 grain purchase, forward ethanol, distillers grains and 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 grain 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 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. We utilize derivative financial instruments, primarily exchange traded commodity future contracts, in conjunction with certain of our grain procurement activities.

Refined Coal

On August 10, 2017, we purchased the entire ownership interest of an entity that owns a refined coal facility, through a 95.35% owned subsidiary, for approximately $12.0 million. We began operating the refined coal facility immediately after the acquisition. We expect that the revenues from the sale of refined coal produced in the facility will be subsidized by federal production tax credits through November 2021, subject to meeting qualified emissions reductions as governed by Section 45 of the Internal Revenue Code. In order to maintain compliance with Section 45 of the Internal Revenue Code, we are required to test the effectiveness of our process with respect to emissions reductions every six months through an independent laboratory. Annually, the IRS publishes the amount of federal income tax credit earned per ton of refined coal produced and sold. We expect to earn credits at the rate of approximately $7.17 per ton of refined coal produced and sold during calendar year 2019.

The refined coal facility is located at the site of a utility-owned electrical generating power station, which is our refined coal operation’s sole customer. We expect future period refined coal production and sales amounts to vary depending on fluctuations in demand from the site host utility, which generally changes based upon weather conditions in the geographic markets the utility serves and competing fuel prices and supplies. We have contracted with an experienced third party to operate and maintain the refined coal facility and to provide us with management reporting and operating data as required. We do

not have any employees on site at the refined coal facility.

Future Energy

During fiscal year 2013, we entered into a joint venture with Hytken HPGP, LLC (“Hytken”) to file and defend patents for eSteam technology relating to heavy oil and oil sands production methods, and to commercially exploit the technology to generate license fees, royalty income and development opportunities. The patented technology is an enhanced method of heavy oil recovery involving zero emissions downhole steam generation. We own 60% and Hytken owns 40% of the entity named Future Energy, LLC (“Future Energy”).

We have agreed to fund direct patent expenses relating to patent applications and defense, annual annuity fees and maintenance on a country by country basis, with the right to terminate funding and transfer related patent rights to Hytken. We have funded all costs relating to new intellectual property, consultants, research and development, pilot field tests and equipment purchases with respect to the proposed commercialization stage of the technology. To date, we have paid approximately $2.2 million cumulatively primarily for patents, purchases of certain equipment and other expenses. We have not yet tested or proven the commercial feasibility of the technology.

Critical Accounting Policies and Estimates

During the three months ended October 31, 2019, we did not change any of our critical accounting policies as disclosed in our 2018 Annual Report on Form 10-K as filed with the Securities and Exchange Commission on March 29, 2019.

Fiscal Year

All references in this report to a particular fiscal year are to REX’s fiscal year ended January 31. For example, “fiscal year 2019” means the period February 1, 2019 to January 31, 2020.

Results of Operations

For a detailed analysis of period to period changes, see the segment discussion that follows this section as that discussion reflects how management views and monitors our business.

Trends and Uncertainties

During fiscal year 2019, operating results in our ethanol and by-products segment have been adversely affected by a weak margin environment highlighted by higher costs for corn, lower availability of local corn and resulting reductions in plant production volumes. Weather conditions delayed the planting of corn in much of the United States, and there continues to be uncertainty regarding the availability of corn on a regional basis. Through the first nine months of fiscal year 2019, we have struggled to obtain adequate supplies of corn, on a consistent basis, at acceptable price levels. Consequently, we have not been able to operate our NuGen ethanol plant at production levels near our historical averages. We cannot reasonably predict the likelihood of future period production levels compared to historical averages.

Under the U.S. Renewable Fuel Standard (“RFS”), the Environmental Protection Agency (“EPA”) assigns individual refiners, blenders and importers the volume of renewable fuels they are obligated to use based on their percentage of total domestic transportation fuel sales. The EPA can waive the obligation for individual small refineries that are experiencing “disproportionate economic hardship” due to compliance with the RFS. Until recent years, the EPA approved relatively few such waivers. The EPA has approved 31 small-refinery exemptions from their 2018 Renewable Fuel Standard compliance obligations, which is estimated to effectively reduce the obligation for ethanol in 2018 by 1.4 billion gallons. The EPA previously granted waivers for 2016 and 2017 totaling approximately 2.6 billion gallons. These actions affect current year demand as obligated parties such as refiners can use the waivers granted by the EPA to help them meet their obligations in different years. There continues to be uncertainty regarding how the EPA will administer the small refiner waivers for 2019. We believe the waivers have resulted in reduced domestic ethanol demand.

During fiscal year 2019, operating results in our refined coal segment have been adversely affected by lower utility plant demand (our only customer). Projections, provided by the utility plant, for the next twelve months indicate this trend may continue. While this leads to lower pre-tax loss amounts from this segment, it also leads to lower tax benefits from Section 45 credits being recognized. Ultimately, this results in lower amounts of segment profit.

Should these trends and uncertainties continue, our future operating results are likely to be negatively impacted.

Comparison of Three and Nine Months Ended October 31, 2019 and 2018

Net sales and revenue in the quarter ended October 31, 2019 were approximately $86.7 million compared to approximately $123.8 million in the prior year’s third quarter, representing a decrease of approximately $37.1 million, which was primarily caused by lower sales in our ethanol and by-products segment of approximately $36.9 million. Net sales and revenue in the first nine months of fiscal year 2019 were approximately $297.1 million compared to approximately $373.3 million in the first nine months of fiscal year 2018, representing a decrease of approximately $76.2 million, which was primarily caused by lower sales in our ethanol and by-products segment of approximately $75.9 million. The decline in ethanol and by-products segment net sales and revenue reflects significantly lower production volumes incurred during fiscal year 2019. This relates primarily to operations at NuGen, as weather related logistical delays and diminished local availability of corn negatively impacted production levels.

Gross loss for the third quarter of fiscal year 2019 was approximately $1.8 million (2.0% of net sales and revenue) which was approximately $9.5 million lower compared to gross profit of approximately $7.7 million of gross profit (6.3% of net sales and revenue) for the third quarter of fiscal year 2018. Gross profit for the third quarter of fiscal year 2019 decreased by approximately $11.2 million compared to the prior year third quarter as a result of operations in the ethanol and by-products segment. Gross loss in the refined coal segment was $1.8 million in the third quarter of fiscal year 2019 compared to $3.5 million in the third quarter of fiscal year 2018. Gross profit for the first nine months of fiscal year 2019 was approximately $5.9 million (2.0% of net sales and revenue) which was approximately $22.1 million lower compared to approximately $28.0 million (7.5% of net sales and revenue) for the first nine months of fiscal year 2018. Gross profit for the first nine months of fiscal year 2019 decreased by approximately $26.2 million compared to the first nine months of fiscal year 2018 as a result of operations in the ethanol and by-

products segment and increased by approximately $4.1 million as a result of operations in the refined coal segment.

SG&A expenses were approximately $4.1 million for the third quarter of fiscal year 2019, which was approximately $1.3 million lower compared to approximately $5.4 million for the third quarter of fiscal year 2018. SG&A expenses were approximately $13.6 million for the first nine months of fiscal year 2019, which was approximately $2.5 million lower compared to approximately $16.1 million for the first nine months of fiscal year 2018. Both the quarterly and year to date decreases were primarily related to a decrease in incentive compensation expense associated with lower profitability in fiscal year 2019 and a decrease in commission expense related to the refined coal acquisition.

During the third quarter of fiscal year 2019, we recognized a loss of approximately $15,000 compared to income of approximately $611,000 for the third quarter of fiscal year 2018, from our equity investment in Big River, which is included in our ethanol and by-products segment results. Such income was approximately $350,000 and approximately $2,182,000 during the first nine months of fiscal year 2019 and 2018, respectively. Big River has interests in four ethanol production plants that shipped approximately 430 million gallons in the trailing twelve months ended October 31, 2019 and has an effective ownership of ethanol gallons shipped for the same period of approximately 370 million gallons. Big River’s operations also include agricultural elevators. 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 $1.0 million for the third quarter of fiscal year 2019 versus approximately $0.8 million for the third quarter of fiscal year 2018. Interest and other income was approximately $3.4 million for the first nine months of fiscal year 2019 versus approximately $2.2 million for the first nine months of fiscal year 2018. Income has increased as yields on our excess cash improved compared to fiscal year 2018 and excess cash investment balances increased in fiscal year 2019.

As a result of the foregoing, loss before income taxes was approximately $4.9 million for the third quarter of fiscal year 2019 versus income of approximately $3.8 million for the third quarter of fiscal year 2018. Loss before income taxes was approximately $4.0 million for the first nine months of fiscal year 2019 versus income of approximately $16.3 million for the first nine months of fiscal year 2018.

Historically, we recorded our interim tax provision or benefit for income taxes including the three and nine months ended October 31, 2018, by applying an estimate of the annual effective tax rate for the full fiscal year to “ordinary” income or loss (pre-tax income or loss excluding unusual or infrequently occurring discrete items) for the reporting period. We determined that since small changes in estimated “ordinary” income would result in significant changes in the estimated annual effective tax rate, the historical method would not provide a reliable estimate for the three and nine months ended October 31, 2019. Thus, we used a discrete effective tax rate method to calculate the provision or benefit for income taxes for the three and nine months ended October 31, 2019. Our tax benefit was approximately 65.9% and approximately 266.7% for the three months ended October 31, 2019 and 2018, respectively, and was approximately 234.7% and approximately 112.8% for the first nine months of fiscal years 2019 and 2018, respectively. The fluctuation in the rate results primarily from the production tax credits we expect to receive associated with our refined coal segment relative to pre-tax income or loss.

As a result of the foregoing, net loss was approximately $1.7 million for the third quarter of fiscal year 2019 compared to net income of approximately $13.8 million for the third quarter of fiscal year 2018. Net income was approximately $5.4 million for the first nine months of fiscal year 2019 compared to approximately $34.6 million for the first nine months of fiscal year 2018.

Income related to noncontrolling interests was approximately $0.4 million and approximately $1.9 million during the third quarters of fiscal years 2019 and 2018, respectively, and was approximately $2.4 million and approximately $4.0 million during the first nine months of fiscal years 2019 and 2018, respectively. These amounts represent the other owners’ share of the income or loss of NuGen, One Earth, the refined coal entity and Future Energy.

As a result of the foregoing, net loss attributable to REX common shareholders for the third quarter of fiscal year 2019 was approximately $2.1 million, a decrease of approximately $13.9 million from net income attributable to REX common shareholders of approximately $11.9 million for the third quarter of fiscal year 2018. Net income attributable to REX common shareholders for the first nine months of fiscal year 2019 was approximately $3.0 million, a decrease of approximately $27.6 million from approximately $30.6 million for the first nine months of fiscal year 2018.

Business Segment Results

We have two reportable segments: i) ethanol and by-products; and ii) refined coal. We evaluate the performance of each reportable segment based on segment profit. Segment profit excludes indirect interest income and certain other items that are included in net income determined in accordance with accounting principles generally accepted in the United States of America. Segment profit includes realized and unrealized gains and losses on derivative financial instruments and the provision/benefit for income taxes.

The following sections discuss the results of operations for each of our business segments and corporate and other. Amounts in the corporate and other category include activities that are not separately

reportable or related to a segment. The following tables summarizes segment and other results (amounts in thousands):

Ethanol and by-Products

The ethanol and by-products segment includes the consolidated financial results of One Earth and NuGen, our equity investment in Big River and certain administrative expenses.

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

The following table summarizes selected operating data from One Earth and NuGen:

Ethanol sales decreased from approximately $91.5 million in the third quarter of fiscal year 2018 to approximately $66.1 million in the third quarter of fiscal year 2019, primarily a result of a 33% decrease in gallons sold compared to the third quarter of fiscal year 2018. This was partially offset as we realized an increased selling price per gallon of $0.11 in the third quarter of fiscal year 2019 compared to the third quarter of fiscal year 2018. Dried distillers grains sales decreased from approximately $24.7 million in the third quarter of fiscal year 2018 to approximately $16.6 million in the third quarter of fiscal year 2019, primarily a result of a 30% decrease in tons sold compared to the third quarter of fiscal year 2018. In addition, a $5.10 decrease in the price per ton sold compared to the third quarter of fiscal year 2018 also contributed to lower dried distillers grains sales. Non-food grade corn oil sales were approximately $3.1 million in the third quarter of fiscal year 2019 compared to approximately $5.0 million in the third quarter

of fiscal year 2018. The decrease was primarily a result of a 41% decrease in pounds sold compared to the third quarter of fiscal year 2018. Modified distillers grains sales were approximately $0.7 million in in the third quarter of fiscal year 2019 compared to approximately $2.3 million in the third quarter of fiscal year 2018. The decrease was primarily a result of a 75% decrease in tons sold compared to the third quarter of fiscal year 2018. The above noted volume decreases were primarily a result of diminished local supplies of corn which prevented us from operating our NuGen ethanol plant at or near historical production levels.

Ethanol sales decreased from approximately $283.7 million in the first nine months of fiscal year 2018 to approximately $227.0 million in the first nine months of fiscal year 2019, primarily a result of a decrease of 21% decrease in gallons sold. Dried distillers grains sales decreased from approximately $65.8 million in the first nine months of fiscal year 2018 to approximately $51.2 million in the first nine months of fiscal year 2019, primarily a result of a 20% decrease in tons sold compared to the first nine months of fiscal year 2018. Non-food grade corn oil sales decreased from approximately $15.0 million in the first nine months of fiscal year 2018 to approximately $12.7 million in the first nine months of fiscal year 2019, primarily a result of a 19% decrease in pounds sold. Modified distillers grains sales decreased from approximately $8.1 million in the first nine months of fiscal year 2018 to approximately $5.8 million in the first nine months of fiscal year 2019, primarily a result of a 27% decrease in tons sold. The volume decreases discussed above, which relate primarily to operations at NuGen, resulted from weather related logistical delays and diminished local availability of corn which negatively impacted production levels. Because of uncertainty regarding the availability of corn, we do not have an estimate of future periods’ sales volume.

Gross profit for the third quarter of fiscal year 2019 was approximately $28,000 (0% of net sales and revenue), which was approximately $11.2 million lower compared to approximately $11.3 million of gross profit (9.1% of net sales and revenue) for the third quarter of fiscal year 2018. The crush spread for the third quarter of fiscal year 2019 was approximately $(0.04) per gallon of ethanol sold compared to $0.13 per gallon of ethanol sold during the third quarter of fiscal year 2018. There are concerns regarding the availability of local corn until the 2020 corn harvest. This could lead to future period corn price increases and/or acceptable supplies of corn may not be sufficiently available. The decrease of approximately $11.6 million in sales of dried distillers grains, non-food grade corn oil and modified distillers grains compared to the third quarter of fiscal year 2018 negatively affected gross profit.

Grain accounted for approximately 78% ($67.7 million) of our cost of sales during the third quarter of fiscal year 2019 compared to approximately 76% ($84.9 million) during the third quarter of fiscal year 2018. Natural gas accounted for approximately 4% ($3.2 million) of our cost of sales during the third quarter of fiscal year 2019 compared to approximately 5% ($5.5 million) during the third quarter of fiscal year 2018. Both the grain and natural gas dollar decreases were primarily attributable to the lower production levels incurred in the third quarter of fiscal year 2019 relative to the third quarter of fiscal year 2018 levels.

Gross profit for the first nine months of fiscal year 2019 was approximately $12.3 million (4.1% of net sales and revenue), which was approximately $26.2 million lower compared to approximately $38.5 million of gross profit (10.3% of net sales and revenue) for the first nine months of fiscal year 2018. The crush spread for the first nine months of fiscal year 2019 was approximately $0.03 per gallon of ethanol sold compared to approximately $0.13 per gallon of ethanol sold during the first nine months of fiscal year 2018. The decrease of approximately $19.2 million in sales of dried distillers grains, non-food grade corn

oil and modified distillers grains compared to the first nine months of fiscal year 2018 negatively affected gross profit.

Grain accounted for approximately 78% ($221.3 million) of our cost of sales during the first nine months of fiscal year 2019 compared to approximately 77% ($256.7 million) during the first nine months of fiscal year 2018. Natural gas accounted for approximately 5% ($13.5 million) of our cost of sales during the first nine months of fiscal year 2019 compared to approximately 5% ($17.0 million) during the first nine months of fiscal year 2018. The decrease in dollars for both grain and natural gas was primarily attributable to the lower production levels incurred in fiscal year 2019 relative to fiscal year 2018 levels.

We attempt to match quantities of ethanol, distillers grains and non-food grade corn oil sales contracts with an appropriate quantity of grain 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.

SG&A expenses for the third quarter of fiscal year 2019 were approximately $3.6 million, compared to the third quarter of fiscal year 2018 amount of approximately $4.0 million. SG&A expenses were approximately $11.6 million for the first nine months of fiscal year 2019, compared to the first nine months of fiscal year 2018 amount of $12.6 million. Both the quarterly and year to date decreases were primarily related to a decrease in incentive compensation expense associated with lower profitability in fiscal year 2019.

During the third quarter of fiscal year 2019 we recognized a loss of approximately $15,000 compared to income of approximately $611,000 for the third quarter of fiscal year 2018, from our equity investment in Big River. Such income was approximately $350,000 and approximately $2,182,000 during the first nine months of fiscal year 2019 and 2018, respectively. Big River has interests in four ethanol production plants that shipped approximately 430 million gallons in the trailing twelve months ended October 31, 2019 and has an effective ownership of ethanol gallons shipped for the same period of approximately 370 million gallons. Big River’s operations also include agricultural elevators. 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 $0.7 million for the third quarter of fiscal year 2019 compared to approximately $0.6 million for the third quarter of fiscal year 2018. Interest and other income was approximately $2.4 million for the first nine months of fiscal year 2019 versus approximately $1.4 million for the first nine months of fiscal year 2018. Income has increased as yields on our excess cash improved compared to fiscal year 2018 and the balance of our excess cash invested has increased compared to fiscal year 2018.

The benefit for income taxes was approximately $0.9 million in the third quarter of fiscal year 2019 compared to approximately $1.6 million in the third quarter of fiscal year 2018. The provision for income

taxes was approximately $0.2 million in the first nine months of fiscal year 2019 compared to approximately $1.8 million in the first nine months of fiscal year 2018. The fluctuation in segment income tax provision is primarily related to federal research and experimentation tax credits recognized in fiscal year 2018 and lower pre-tax income during fiscal year 2019.

Income related to noncontrolling interests was approximately $0.5 million and approximately $2.1 million during the third quarters of fiscal years 2019 and 2018, respectively. Income related to noncontrolling interests was approximately $2.6 million and approximately $4.6 million during the first nine months of fiscal years 2019 and 2018, respectively. These amounts represent the other owners’ share of the income of NuGen and One Earth.

Segment loss for the third quarter of fiscal year 2019 was approximately $2.3 million, which was a decrease of approximately $10.3 million compared to the prior year third quarter segment profit of approximately $7.9 million. Segment profit for the first nine months of fiscal year 2019 was approximately $0.7 million, which was approximately $22.4 million lower compared to the first nine months of fiscal year 2018 amount of approximately $23.1 million.

Refined Coal

The refined coal segment includes the consolidated financial results of our refined coal entity and certain administrative expenses. We acquired the refined coal entity during the third quarter of fiscal year 2017. The following table summarizes sales from refined coal operations by product group (amounts in thousands):

¹ We record sales in the refined coal segment net of the cost of coal as we purchase the coal feedstock from the customer to which refined coal is sold.

Refined coal sales were approximately $0.1 million and approximately $0.2 million in the third quarters of fiscal years 2019 and 2018, respectively. These sales were approximately $0.3 million and approximately $0.6 million in the first nine months of fiscal years 2019 and 2018, respectively. During fiscal year 2019, operating results have been adversely affected by lower utility plant demand (our only customer). We expect future period refined coal sales to vary depending on fluctuations in demand from the site host utility, which generally change based upon weather conditions in the geographic markets the utility serves and competing fuel prices and supplies. Based upon current year operations and projections from the site host utility, we expect lower demand for refined coal in future periods compared to historical results.

Gross loss was approximately $1.8 million and approximately $3.5 million in the third quarters of fiscal year 2019 and 2018, respectively. Gross loss was approximately $6.4 million and approximately $10.5 million in the first nine months of fiscal year 2019 and 2018, respectively. We expect future period gross losses to vary like the sales fluctuations described above. Based upon the agreements in place that

govern the operation, sales and purchasing activities of the refined coal plant, we expect the refined coal operation to continue operating at a gross loss. We expect that the ongoing losses will be subsidized by federal production income tax credits.

SG&A expenses were approximately $(0.1) million and approximately $0.7 million in the third quarters of fiscal years 2019 and 2018, respectively. Such expenses were approximately $(0.1) million and approximately $1.4 million in the first nine months of fiscal years 2019 and 2018, respectively. We expect future period expenses to be less than $1.0 million per quarter. The fiscal year 2019 expenses were reduced as estimates of future refined coal production have been reduced.

Loss related to noncontrolling interests was approximately $0.1 million and approximately $0.2 million in the third quarters of fiscal years 2019 and 2018, respectively. Loss related to noncontrolling interests was approximately $0.3 million and approximately $0.5 million in the first nine months of fiscal years 2019 and 2018, respectively. This amount represents the other owner’s share of the pre-tax loss of refined coal operations.

The benefit for income taxes was approximately $2.2 million and approximately $8.3 million in the third quarters of fiscal years 2019 and 2018, respectively. The benefit for income taxes was approximately $9.3 million and approximately $19.9 million in the first nine months of fiscal years 2019 and 2018, respectively. The refined coal segment tax benefit is comprised of an estimated statutory benefit of its pre-tax losses and an estimated benefit from the federal production tax credits we expect to earn from producing and selling refined coal. The amount of benefit we recognize during interim periods will fluctuate based on actual production and profitability levels.

As a result of the foregoing, including the benefit of federal production tax credits associated with refined coal production and sales, segment profit was approximately $0.6 million and approximately $4.3 million for the third quarters of fiscal years 2019 and 2018, respectively. Segment profit was approximately $3.2 million and approximately $8.5 million for the first nine months of fiscal years 2019 and 2018, respectively.

Corporate and Other

SG&A expenses were approximately $0.7 million for each of the third quarters of fiscal years 2019 and 2018. These expenses were approximately $2.1 million for each of the first nine months of fiscal years 2019 and 2018, respectively.

Interest and other income was approximately $0.3 million for each of the third quarters of fiscal years 2019 and 2018. Interest and other income was approximately $0.9 million and approximately $0.8 million for the first nine months of fiscal years 2019 and 2018, respectively.

Liquidity and Capital Resources

Net cash used in operating activities was approximately $2.3 million for the first nine months of fiscal year 2019, compared to cash provided of approximately $28.9 million for the first nine months of fiscal year 2018. For the first nine months of fiscal year 2019, cash was provided by net income of approximately $5.4 million, adjusted for non-cash items of approximately $12.3 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 and stock based compensation expense. We received dividends from Big River of approximately $1.0 million during the first nine months of fiscal year 2019. An increase in the balance of accounts receivable used cash of approximately $5.0 million, which was primarily a result of amounts owed by One Earth’s sole corn provider (until the end of the third quarter) and the timing of customer payments and shipments. Beginning in the fourth quarter of fiscal year 2019, One Earth is sourcing its own corn and in conjunction with this change One Earth was owed approximately $6.7 million at the end of the third quarter from the previous corn originator. An increase in the balance of inventories used cash of approximately $12.6 million, which was primarily a result of the timing of receipt of raw materials, plant shutdowns and the shipment of finished goods. An increase in the balance of accounts payable provided 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 $9.0 million, which was primarily a result of payments of operating leases and incentive compensation as well as lower accruals for utilities.

Net cash provided by operating activities was approximately $28.9 million for the first nine months of fiscal year 2018. For the first nine months of fiscal year 2018, cash was provided by net income of approximately $34.6 million, adjusted for non-cash items of approximately ($5.9) million, which consisted of depreciation, income from equity method investments, interest income from short-term investments, the deferred income tax provision and stock based compensation expense. We received dividends from Big River of approximately $3.0 million during the first nine months of fiscal year 2018. An increase in the balance of accounts receivable used cash of approximately $2.8 million, which was primarily a result of the timing of customer shipments and payments. An increase in the balance of inventories used cash of approximately $0.9 million, which was primarily a result of the timing of receipt of raw materials. An increase in refundable income taxes of approximately $1.7 million was primarily a result of recognizing the benefit of an expected filing of an amended income tax return to claim a refund for prior years. An increase in the balance of accounts payable provided cash of approximately $1.7 million, which was primarily a result of the timing of inventory receipts and vendor payments. An increase in the balance of other liabilities provided cash of approximately $2.1 million which was primarily a result of unrecognized tax benefits related to certain tax credits.

At October 31, 2019, working capital was approximately $236.1 million, compared to approximately $233.6 million at January 31, 2019. The ratio of current assets to current liabilities was 10.7 to 1 at October 31, 2019 and 14.7 to 1 at January 31, 2019.

Cash of approximately $12.7 million was provided by investing activities for the first nine months of fiscal year 2019, compared to cash used of approximately $21.8 million during the first nine months of fiscal year 2018. During the first nine months of fiscal year 2019, we had capital expenditures of approximately $2.6 million. We expect to spend between $5 million and $6 million during the remainder of fiscal year 2019 on various capital projects. During the first nine months of fiscal year 2019, we sold United States treasury bills (classified as short-term investments) of approximately $15.0 million. Depending on investment options available, we may elect to retain the funds, or a portion thereof, in cash investments, short-term investments or long-term investments.

Cash of approximately $21.8 million was used in investing activities for the first nine months of fiscal year 2018. During the first nine months of fiscal year 2018, we had capital expenditures of

approximately $8.0 million, the majority of which were capacity expansion projects at the One Earth and NuGen ethanol plants. During the first nine months of fiscal year 2018, we used cash of approximately $126.0 million for the purchase of United States treasury bills to increase the interest income we receive on our excess cash balances. As these were all short-term investments, approximately $112.1 million of the treasury bills matured during the first nine months of fiscal year 2018.

Cash of approximately $2.3 million was used in financing activities for the first nine months of fiscal year 2019, compared to cash used of approximately $19.7 million during the first nine months of fiscal year 2018. During the first nine months of fiscal year 2019, we used cash of approximately $2.6 million to pay dividends to and to purchase shares from noncontrolling members. During the first nine months of fiscal year 2019, we received approximately $0.3 million in capital contributions from the minority investor in the refined coal entity.

Cash used in financing activities totaled approximately $19.7 million for the first nine months of fiscal year 2018. During the first nine months of fiscal year 2018, we used cash of approximately $18.4 million to purchase approximately 253,000 shares of our common stock in open market transactions. During the first nine months of fiscal year 2018, we used cash of approximately $1.7 million to purchase membership interests from and pay dividends to noncontrolling members of One Earth. During the first nine months of fiscal year 2018, we received approximately $0.4 million in capital contributions from the minority investor in the refined coal entity.

We are investigating various uses for our excess cash and short-term investments. We have a stock buyback program, and given our current authorization level, can repurchase a total of approximately 350,000 shares. We also plan to seek and evaluate investment opportunities including energy related, agricultural or other ventures we believe fit our investment criteria in addition to investing in highly liquid short-term securities.

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 changes, the price volatility and availability of corn, distillers grains, ethanol, non-food grade corn oil, gasoline, natural gas, our ethanol and refined coal plants operating efficiently and according to forecasts and projections, changes in the international, national or regional economies, weather, results of income tax audits, changes in income tax laws or regulations 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, 2019 (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 purchase and sale contracts. At October 31, 2019, One Earth and NuGen combined have forward purchase contracts for approximately 4.4 million bushels of corn, the principal raw material for their ethanol plants. One Earth and NuGen expect to take delivery of the corn through January 2020. At October 31, 2019, One Earth and NuGen combined have forward purchase contracts for approximately 1,067,000 MmBtu of natural gas. They expect to take delivery of the natural gas through February 2020. At October 31, 2019, One Earth and NuGen have combined sales commitments for approximately 18.9 million gallons of ethanol, approximately 48,500 tons of distillers grains and approximately 6.1 million pounds of non-food grade corn oil. One Earth and NuGen expect to deliver the majority of the ethanol, distillers grains and non-food grade corn oil through December 2019. Our exposure to market risk, which includes the impact of our risk management activities, is based on the estimated effect on pre-tax income starting on October 31, 2019 is as follows (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 not party to any legal proceedings that we believe would, individually or in the aggregate, have a material adverse effect on our financial condition, results of operations or cash flows.

Item 1A. Risk Factors

During the quarter ended October 31, 2019, 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, 2019.

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

Dividend Policy

REX did not pay dividends in the current or prior years. We currently have no restrictions on the payment of dividends. None of our consolidated subsidiaries have restrictions on their ability to pay dividends to us. During the first nine months of fiscal year 2019, One Earth and NuGen combined paid dividends to REX of approximately $10.6 million. During the first nine months of fiscal year 2018, One Earth and NuGen combined paid dividends to REX of approximately $5.1 million.

Item 3. Defaults upon Senior Securities

Not Applicable

Item 4. Mine Safety Disclosures

Not Applicable

Item 5. Other Information

None

Item 6. Exhibits

The following exhibits are filed with this report: