UNITED STATES


SECURITIES AND EXCHANGE COMMISSION


WASHINGTON, D.C. 20549

 

 

 

FORM 10-Q

 

(Mark One)

 

xQUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
 For the quarterly period ended OctoberJuly 31, 20162017
 OR
oTRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
  
 For the transition period from _________ to _________

 

Commission File Number 001-09097

 

 

 

REX AMERICAN RESOURCES CORPORATION

(Exact name of registrant as specified in its charter)

 

 

 

Delaware31-1095548
(State or other jurisdiction of(I.R.S. Employer
incorporation or organization)Identification Number)
  
7720 Paragon Road, Dayton, Ohio45459
(Address of principal executive offices)(Zip Code)

 

(937) 276-3931

(Registrant’s telephone number, including area code)

 

 

 

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.              Yesx  No¨o

 

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files).               Yesx  No¨o

 

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

Large accelerated filero¨Accelerated filerx
Non-accelerated filer¨o (Do not check if a smaller reporting company)Smaller reporting company¨o
Emerging growth companyo

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

 

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

Yes¨o  Nox

At the close of business on November 30, 2016September 5, 2017 the registrant had 6,582,0296,566,769 shares of Common Stock, par value $.01 per share, outstanding.

 

 
 

REX AMERICAN RESOURCES CORPORATION AND SUBSIDIARIES

 

INDEX

 

  Page
   
PART I.FINANCIAL INFORMATION 
   
Item 1.Financial Statements 
   
 Consolidated Condensed Balance Sheets3
 Consolidated Condensed Statements of Operations4
 Consolidated Condensed Statements of Equity5
 Consolidated Condensed Statements of Cash Flows6
 Notes to Consolidated Condensed Financial Statements7
   
Item 2.Management’s Discussion and Analysis of Financial Condition and Results of Operations20
   
Item 3.Quantitative and Qualitative Disclosures About Market Risk2928
   
Item 4.Controls and Procedures29
   
PART II.OTHER INFORMATION 
   
Item 1.Legal Proceedings3029
   
Item 1A.Risk Factors30
   
Item 2.Unregistered Sales of Equity Securities and Use of Proceeds3032
   
Item 3.Defaults upon Senior Securities3032
   
Item 4.Mine Safety Disclosures3032
   
Item 5.Other Information3032
   
Item 6.Exhibits3032
2

PART I. FINANCIAL INFORMATION

 

Item 1.Financial Statements

 

REX AMERICAN RESOURCES CORPORATION AND SUBSIDIARIES

Consolidated Condensed Balance Sheets

Unaudited

 

 October 31, January 31,  July 31,
2017
 January 31,
2017
 
 2016 2016  (In Thousands) 
Assets   (In Thousands)    
Current assets:                
Cash and cash equivalents $162,753  $135,765  $185,997  $188,576 
Restricted cash  46   54   379   130 
Accounts receivable  13,269   13,666   10,938   11,901 
Inventory  19,483   17,178   22,091   17,057 
Refundable income taxes  1,956   5,254   1,527   1,070 
Prepaid expenses and other  6,680   6,407   7,535   6,959 
Deferred taxes, net  1,537   1,036   -   824 
Total current assets  205,724   179,360   228,467   226,517 
Property and equipment, net  186,219   189,976   187,545   182,761 
Other assets  6,432   6,642   6,720   6,913 
Equity method investments  37,954   38,707   36,665   37,833 
Total assets $436,329  $414,685  $459,397  $454,024 
                
Liabilities and equity:                
Current liabilities:                
Accounts payable, trade $10,999  $10,212  $11,251  $9,171 
Accrued expenses and other current liabilities  10,875   9,423   7,442   13,348 
Total current liabilities  21,874   19,635   18,693   22,519 
Long-term liabilities:                
Deferred taxes  37,786   38,304   40,848   41,135 
Other long-term liabilities  2,227   987   2,260   2,096 
Total long-term liabilities  40,013   39,291   43,108   43,231 
Equity:                
REX shareholders’ equity:                
Common stock  299   299   299   299 
Paid-in capital  145,744   144,844   146,851   145,767 
Retained earnings  495,826   475,874   515,692   508,207 
Treasury stock  (313,844)  (309,754)  (313,658)  (313,838)
Total REX shareholders’ equity  328,025   311,263   349,184   340,435 
Noncontrolling interests  46,417   44,496   48,412   47,839 
Total equity  374,442   355,759   397,596   388,274 
Total liabilities and equity $436,329  $414,685  $459,397  $454,024 

 

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

3

REX AMERICAN RESOURCES CORPORATION AND SUBSIDIARIES

Consolidated Condensed Statements Ofof Operations

Unaudited

 

 Three Months
 Ended
 Nine Months
 Ended
 
 October 31, October 31,  Three Months
Ended
July 31,
 Six Months
Ended
July 31,
 
 2016 2015 2016 2015  2017 2016 2017 2016 
            
 (In Thousands, Except Per Share Amounts)  (In Thousands, Except Per Share Amounts) 
            
Net sales and revenue $116,283  $110,584  $332,212  $329,261  $108,744  $115,707  $221,887  $215,929 
Cost of sales  96,121   96,311   286,344   287,585   97,963   98,423   198,617   190,223 
Gross profit  20,162   14,273   45,868   41,676   10,781   17,284   23,270   25,706 
Selling, general and administrative expenses  (5,082)  (4,720)  (14,315)  (15,629)  (4,779)  (5,206)  (10,181)  (9,233)
Equity in income of unconsolidated affiliates  1,838   1,314   3,257   7,857   137   1,186   837   1,419 
Gain on sale of investment        192   10,385 
(Loss) gain on sale of investment  (13)  -   (13)  192 
Gain on disposal of property and equipment, net  179   1   364   496   13   185   13   185 
Interest and other income  117   199   374   524   334   97   549   257 
Income before income taxes  17,214   11,067   35,740   45,309   6,473   13,546   14,475   18,526 
Provision for income taxes  (5,740)  (1,634)  (11,771)  (12,726)  (2,302)  (4,517)  (4,692)  (6,031)
Net income  11,474   9,433   23,969   32,583   4,171   9,029   9,783   12,495 
Net income attributable to noncontrolling interests  (2,536)  (1,977)  (4,017)  (4,833)  (1,230)  (853)  (2,298)  (1,481)
Net income attributable to REX common shareholders $8,938  $7,456  $19,952  $27,750  $2,941  $8,176  $7,485  $11,014 
                                
Weighted average shares outstanding – basic and diluted  6,590   6,915   6,591   7,460   6,593   6,586   6,592   6,590 
                                
Basic and diluted net income per share attributable to REX common shareholders $1.36  $1.08  $3.03  $3.72  $0.45  $1.24  $1.14  $1.67 

 

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

4

REX AMERICAN RESOURCES CORPORATION AND SUBSIDIARIES

Consolidated Condensed Statements Ofof Equity

Unaudited

(In Thousands)

 

 REX Shareholders      REX Shareholders     
                  Common Shares           
 Common Shares              Issued Treasury Paid-in Retained Noncontrolling Total 
 Issued  Treasury  Paid-in  Retained  Noncontrolling  Total  Shares Amount Shares Amount Capital Earnings Interests Equity 
 Shares  Amount  Shares  Amount  Capital  Earnings  Interests  Equity                  
Balance at January 31, 2017  29,853  $299   23,292  $(313,838) $145,767  $508,207  $47,839  $388,274 
                                
Net income                      7,485   2,298   9,783 
                                
Issuance of equity awards and stock based compensation expense          (5)  180   1,084           1,264 
                                
Noncontrolling interests distribution and other  -   -   -   -   -   -   (1,725)  (1,725)
                                
Balance at July 31, 2017  29,853  $299   23,287  $(313,658) $146,851  $515,692  $48,412  $397,596 
                                                                
Balance at January 31, 2016  29,853  $299   23,204  $(309,754) $144,844  $475,874  $44,496  $355,759   29,853  $299   23,204  $(309,754) $144,844  $475,874  $44,496  $355,759 
                                                                
Net income                      19,952   4,017   23,969                       11,014   1,481   12,495 
                                                                
Treasury stock acquired          88   (4,353)              (4,353)          88   (4,353)              (4,353)
                                                                
Issuance of equity awards and stock based compensation expense          (22)  263   900           1,163 
Stock based compensation expense          -   258   877           1,135 
                                                                
Noncontrolling interests distribution and other                    (2,096)  (2,096)  -   -   -   -   -   -   (2,096)  (2,096)
                                                                
Balance at October 31, 2016  29,853  $299   23,270  $(313,844) $145,744  $495,826  $46,417  $374,442 
                                
                                
Balance at January 31, 2015  29,853  $299   21,954  $(239,557) $144,791  $444,438  $42,993  $392,964 
                                
Net income                      27,750   4,833   32,583 
                                
Treasury stock acquired          1,044   (60,116)              (60,116)
                                
Issuance of equity awards and stock based compensation expense          (3)  5   23           28 
                                
Noncontrolling interests distribution and other                    (605)  (605)
                                
Balance at October 31, 2015  29,853  $299   22,995  $(299,668) $144,814  $472,188  $47,221  $364,854 
Balance at July 31, 2016  29,853  $299   23,292  $(313,849) $145,721  $486,888  $43,881  $362,940 

 

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

5

REX AMERICAN RESOURCES CORPORATION AND SUBSIDIARIES

Consolidated Condensed Statements Ofof Cash Flows

Unaudited

 

 Nine Months Ended 
 October 31,  Six Months Ended
July 31,
 
 2016 2015  2017 2016 
 (In Thousands)  (In Thousands) 
Cash flows from operating activities:                
Net income including noncontrolling interests $23,969  $32,583  $9,783  $12,495 
Adjustments to reconcile net income to net cash provided by operating activities:                
Depreciation, impairment charges and amortization  14,567   14,193 
Depreciation and amortization  9,955   9,748 
Income from equity method investments  (3,257)  (7,857)  (837)  (1,419)
Dividends received from equity method investee  2,005   1,504 
Gain on disposal of real estate and property and equipment, net  (364)  (496)  (13)  (185)
Dividends received from equity method investees  4,010   7,643 
Gain on sale of investment  (192)  (10,385)
Loss (gain) on sale of investment  13   (192)
Deferred income tax  (1,019)  (8,078)  537   - 
Stock based compensation expense  68   23   350   40 
Changes in assets and liabilities:                
Accounts receivable  (1,686)  (2,307)  886   (4,250)
Inventories  (2,305)  (5,494)  (5,034)  (6,455)
Other assets  2,758   (51)  (953)  2,989 
Accounts payable, trade  1,653   4,913   1,678   (3,087)
Other liabilities  3,157   (2,849)  (4,828)  169 
Net cash provided by operating activities  41,359   21,838   13,542   11,357 
Cash flows from investing activities:                
Capital expenditures  (11,836)  (9,852)  (14,366)  (9,334)
Restricted cash  8   (20)  (249)  (56)
Restricted investments and deposits  460   250   100   409 
Proceeds from sale of investment  2,275   45,476   64   2,275 
Proceeds from sale of real estate and property and equipment, net  1,510   1,936   42   1,028 
Other  17   17   13   12 
Net cash (used in) provided by investing activities  (7,566)  37,807 
Net cash used in investing activities  (14,396)  (5,666)
Cash flows from financing activities:                
Dividend payments to and purchases of stock from noncontrolling interests holders  (2,096)  (605)  (1,725)  (2,096)
Treasury stock acquired  (4,709)  (60,111)  -   (4,709)
Net cash used in financing activities  (6,805)  (60,716)  (1,725)  (6,805)
Net increase (decrease) in cash and cash equivalents  26,988   (1,071)
Net decrease in cash and cash equivalents  (2,579)  (1,114)
Cash and cash equivalents, beginning of period  135,765   137,697   188,576   135,765 
Cash and cash equivalents, end of period $162,753  $136,626  $185,997  $134,651 
                
Non cash investing activities – Accrued capital expenditures $1,183  $1,216  $744  $1,350 
Non cash financing activities – Equity awards issued $1,095  $ 
Non cash financing activities – Stock awards accrued $281  $- 
Non cash financing activities – Stock awards issued $1,195  $1,095 

 

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

6

REX AMERICAN RESOURCES CORPORATION AND SUBSIDIARIES

 

NOTES TO UNAUDITED CONSOLIDATED CONDENSED FINANCIAL STATEMENTS
October

July 31, 20162017

 

Note 1.Consolidated Condensed Financial Statements

 

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, 20162017 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, 20162017 (fiscal year 2015)2016). 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, 2016.2017. 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 REX American Resources Corporation and its wholly and majority owned subsidiaries. All intercompany balances and transactions have been eliminated. The Company includes the results of operations of One Earth Energy, LLC (“One Earth���Earth”) in its Consolidated Condensed Statements of Operations on a delayed basis of one month.

 

Nature of Operations – The Company operates in one reportable segment, alternative energy, and has equity investments in three ethanol limited liability companies, two of which are majority ownership interests.

 

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 20152016 Annual Report on Form 10-K. While management believes that the procedures followed in the preparation of interim financial information are reasonable, the accuracy of some estimated amounts is dependent upon facts that will exist or calculations that will be accomplished at fiscal year-end. Examples of such estimates include accrued liabilities, such as management bonuses, and the provision for income taxes. Any adjustments pursuant to such estimates during the quarter were of a normal recurring nature. Actual results could differ from those estimates.

7

Revenue Recognition

 

The Company recognizes sales from the production of ethanol, distillers grains and non-food grade corn oil when title transfers to customers, generally upon shipment from the ethanol plant or upon loading of the rail car used to transport the products.

 

Cost of Sales

 

Cost of sales includes direct productiondepreciation, costs of raw materials, inbound freight charges, purchasing and receiving costs, inspection costs, other distribution expenses, warehousing costs, plant management, certain compensations costs, and certaingeneral facility overhead costs such as depreciation, property taxes and utilities related to producing ethanol and related by-products.charges.

 

Selling, General and Administrative Expenses

 

The Company includes non-production related costs such as professional fees, selling charges and certain payroll in selling, general and administrative 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. During fiscal year 2015, the Company began to carry a portion of its forward grain purchase contracts at fair value.

 

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

 

The Company applies an effective tax rate to interim periods that is consistent with the Company’s estimated annual tax rate as adjusted for discrete items impacting the interim periods. The Company’s estimated annual tax rate does not reflect the impact of its refined coal operation and the expected federal income tax credits to be earned beginning in the third quarter of fiscal year 2017 (see Note 16). 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

8

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 income taxes of approximately $5,060,000$6.5 million and $19,703,000

8

$1.0 million during the ninesix months ended OctoberJuly 31, 20162017 and 2015,2016, respectively. The Company received no refunds of income taxes during the ninesix months ended OctoberJuly 31, 2017 and 2016. The Company received refunds of state income taxes of approximately $132,000 during the nine months ended October 31, 2015.

 

As of OctoberJuly 31, 20162017 and January 31, 2016,2017, total unrecognized tax benefits were approximately $2,029,000$2.0 million and $987,000,$1.9 million, respectively. Accrued penalties and interest were approximately $198,000$0.3 million and $0.2 million at OctoberJuly 31, 2016. There were no accrued penalties2017 and interest at January 31, 2016.2017, respectively. If the Company were to prevail on all unrecognized tax benefits recorded, the provision for income taxes would be reduced by approximately $1,319,000.$1.3 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 related to producing ethanol and related by-products.co-products. 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 were no significant permanent write-downs of inventory at OctoberJuly 31, 20162017 and January 31, 2016.2017. 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):

 

 October 31,
2016
 January 31,
2016
  July 31,
2017
 January 31,
2017
 
             
Ethanol and other finished goods $3,470  $3,105  $4,302  $5,262 
Work in process  2,740   2,652   3,074   2,359 
Grain and other raw materials  13,273   11,421   14,715   9,436 
Total $19,483  $17,178  $22,091  $17,057 

 

Property and Equipment

 

Property and equipment is recorded at cost. Depreciation is computed using the straight-line method. Estimated useful lives are 15 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, based on an analysis of undiscounted future expected cash flows from the use and ultimate disposition of the asset. There were no impairment charges in the first ninesix months of fiscal year 2016 and approximately $125,000 of impairmentyears 2017 or 2016. Impairment charges inhave historically resulted from the first nine months of fiscal year 2015, included in cost of sales in the accompanying Consolidated Condensed Statement of Operations. The impairment charges are related to unfavorable changes in real estate

9

conditions in local markets. Impairment charges result from the Company’s management performing cash flow analysis and representhave represented management’s estimate of the excess of net book value over fair value.

 

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 of an asset group 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. The Company generally determines the fair value of the asset group using a discounted cash flow model based on market participant assumptions (for income producing asset groups) or by obtaining appraisals based on the market approach and comparable market transactions (for non-income producing asset groups).

 

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 consolidates the results of two majority owned subsidiaries, One Earth and NuGen.NuGen Energy, LLC (“NuGen”). The results of One Earth are included on a delayed basis of one month lag as One Earth has a fiscal year end of December 31. NuGen has the same fiscal year as the parent, and therefore, there is no lag in reporting the results of NuGen. 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. Any unallocated excess is treated as goodwill and is recorded as a component of the carrying value of the equity method investee. 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 accounted for its investment in Patriot Holdings, LLC (“Patriot”) (through May 31, 2015 – see Note 10 for a discussion of the sale of the Company’s equity interest in Patriot) using the equity method of accounting and included the results on a delayed basis of one month as Patriot had 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.

 

Comprehensive Income

 

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

10

Accounting Changes and Recently Issued Accounting Standards

 

In March 2016, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) No. 2016-09, “Improvements to Employee share-BasedShare-Based Payment Accounting (“ASU 2016-09”). This standard simplifies the accounting treatment for excess tax benefits and deficiencies, forfeitures,

10

and cash flow considerations related to share-based compensation. This standard is effective for annual and interim periods beginning after December 15, 2016. The Company has not determined the effect ofadopted this standard on its consolidated financial statements and related disclosures.

In January 2016,February 1, 2017. The adoption of ASU 2016-09 did not impact the FASB issued ASU 2016-01. “Recognition and Measurement of Financial Assets and Financial Liabilities”. This standard provides guidance for the recognition, measurement, presentation and disclosure of financial instruments. This ASU is effective for annual and interim periods beginning after December 15, 2017, and early adoption is not permitted. The Company has not determined the effect of this standard on itsCompany’s consolidated financial statements and related disclosures.

 

In February 2016, the FASB issued ASU 2016-02 “Leases”. This standard requires that virtually all leases will be recognized by lessees on their balance sheet as a right-of-use asset and a corresponding lease liability, including leases currently accounted for as operating leases. The Company will be required to adopt this standard effective February 1, 2019. The Company has not determinedcompleted its analysis of adopting this guidance but it does expect the effectadoption of this standardguidance to have a material impact on its consolidated financial statementsConsolidated Balance Sheet related to the right to use asset and lease obligation liability to be recognized upon adoption of this guidance. The related disclosures.leases are currently accounted for as operating leases (see Note 3).

 

In August 2016, the FASB issued ASU 2016-15 “Statement of Cash Flows (Topic 230), Classification of Certain Cash Receipts and Cash Payments”. This standard provides guidance on eight specific cash flow issues. The cash flow issues covered by this ASU are: 1) debt prepayment or debt extinguishment costs; 2) settlement of zero-coupon debt instruments or other debt instruments with coupon interest rates that are insignificant in relation to the effective interest rate of the borrowing; 3) contingent consideration payments made after a business combination; 4) proceeds from the settlement of insurance claims; 5) proceeds from the settlement of corporate-owned life insurance policies, including bank-owned life insurance policies; 6) distributions received from equity method investees; 7) beneficial interests in securitization transactions; and 8) separately identifiable cash flows and application of the predominance principle for distributions received from equity method investees in the Statement of Cash Flows. The Company will be required to adopt thisthe amended guidance in ASC Topic 606 “Revenue from Contracts with Customers”, which requires revenue recognition to reflect the transfer of promised goods or services to customers and replaces existing revenue recognition guidance. The updated standard effectivepermits the use of either the retrospective or cumulative effect transition method. The FASB had deferred the required adoption of the amended guidance by one year, from February 1, 2017 to February 1, 2018. The Company hasis progressing in its evaluation of adopting this guidance but it does not determinedexpect the effectadoption of this standardguidance to have a material impact on its consolidated financial statements with respect to measurement and related disclosures.recognition of revenue. The Company expects to adopt this guidance using the modified prospective method. The Company is still evaluating the impact of adopting this guidance on disclosures in the consolidated financial statements.

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In November 2015, the FASB issued ASU 2015-17 “Balance Sheet Classification of Deferred Taxes”, (“ASU 2015-17”) which requires that for a particular tax-paying component of an entity and within a particular tax jurisdiction, all deferred tax liabilities and assets shall be offset and presented as a single noncurrent amount. The Company prospectively adopted the amended guidance effective February 1, 2017. Prior periods were not retrospectively adjusted. The adoption of ASU 2015-17 did not affect net income attributable to REX common shareholders or retained earnings in the presented periods.

Note 3.Leases

 

At OctoberJuly 31, 2016,2017, the Company has lease agreements, as lessee, for rail cars and a natural gas pipeline. All of the leases are accounted for as operating leases. The following table is a summary of future minimum rentals on such leases (amounts in thousands):

 

Years Ended January 31,  Minimum
Rentals
 
     
Remainder of 2017 $1,845 
2018  6,650 
2019  5,872 
2020  4,341 
2021  2,778 
Thereafter  4,169 
Total $25,655 

Years Ended January 31, Minimum
Rentals
 
    
Remainder of 2018 $3,556 
2019  6,910 
2020  5,379 
2021  3,580 
2022  2,948 
Thereafter  1,622 
Total $23,995 
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Note 4.Fair Value

 

The Company applies ASC 820, “Fair Value Measurements and Disclosures”, (“ASC 820”) which provides a framework for measuring fair value underaccounting principles generally accepted in the United States of America.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. The fair values of property and equipment are determined by using various models that discount future expected cash flows.

 

To ensure the prudent application of estimates and management judgementjudgment 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

12

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 OctoberJuly 31, 20162017 are summarized below (amounts in thousands):

 

   Level 1   Level 2   Level 3   Fair Value 
                 
Commodity futures (1) $87  $  $  $87 
Investment in cooperative (2)        333   333 
Total assets $87  $  $333  $420 
Forward purchase contract liability (3) $  $408  $  $408 

  Level 1  Level 2  Level 3  Fair Value 
             
Commodity futures (1) $-  $136  $-  $136 
Forward purchase contract asset (4)  -   237   -   237 
Investment in cooperative (2)  -   -   333   333 
Total assets $-  $373  $333  $706 
                 
Forward purchase contract liability (3) $-  $158  $-  $158 
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Financial assets and liabilities measured at fair value on a recurring basis at January 31, 20162017 are summarized below (amounts in thousands):

 

  Level 1  Level 2  Level 3  Fair Value  Level 1 Level 2 Level 3 Fair Value 
          
Commodity futures (1) $-  $45  $-  $45 
Forward purchase contract asset (4)  -   163   -   163 
Investment in cooperative (2) $  $  $333  $333   -   -   333   333 
Total assets $-  $208  $333  $541 
                                
Forward purchase contracts liability (3) $  $312  $  $312 
Forward purchase contract liability (3) $-  $136  $-  $136 

 

(1) Commodity futures are included in “Prepaid expenses and other current assets” on the accompanying Consolidated Condensed Balance Sheets.

(2) The investment in cooperative is included in “Other 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 forward purchase contract asset is included in “Prepaid expenses and other current assets” 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 OctoberJuly 31, 20162017 or January 31, 2016.2017.

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Note 5.Property and Equipment

 

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

 

  October 31,
2016
  January 31,
2016
 
       
Land and improvements $20,951  $21,598 
Buildings and improvements  23,197   24,543 
Machinery, equipment and fixtures  252,722   237,735 
Construction in progress  2,229   6,094 
   299,099   289,970 
Less: accumulated depreciation  (112,880)  (99,994)
Total $186,219  $189,976 

  July 31,
2017
  January 31,
2017
 
       
Land and improvements $20,965  $20,951 
Buildings and improvements  23,259   23,203 
Machinery, equipment and fixtures  261,772   255,348 
Construction in progress  9,359   1,046 
   315,355   300,548 
Less:  accumulated depreciation  (127,810)  (117,787)
Total $187,545  $182,761 
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Note 6.Other Assets

 

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

 

 October 31,
2016
 January 31,
2016
  July 31,
2017
 January 31,
2017
 
             
Real estate taxes refundable $5,186  $5,091  $5,923  $5,923 
Deposits  205   664   55   155 
Other  1,041   887   742   835 
Total $6,432  $6,642  $6,720  $6,913 

 

Real estate taxes refundable represent amounts due One Earth associated with refunds of previously paid taxes in connection with a tax increment financing arrangement with local taxing authorities. Deposits are with utility and other vendors.

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Note 7.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):

 

 October 31,
2016
 January 31,
2016
  July 31,
2017
 January 31,
2017
 
          
Accrued utility charges $1,947  $2,094  $2,088  $2,414 
Accrued payroll and related items  2,884   3,760   1,344   4,279 
Accrued real estate taxes  1,049   2,716 
Accrued income taxes  3,187      37   2,120 
Accrued real estate taxes  1,188   2,564 
Other  1,669   1,005   2,924   1,819 
Total $10,875  $9,423  $7,442  $13,348 

 

Note 8.Revolving Lines of Credit

 

Effective April 1, 2016, One Earth and NuGen each entered into $10.0 million revolving loan facilities that maturematured April 1, 2017. Any borrowings will be secured byDuring the inventory and accounts receivablesecond quarter of One Earth or NuGen, specific to which entity borrows money under these facilities. These revolving loan facilities are recourse only tofiscal year 2017, One Earth and NuGen and not to REX American Resources Corporation or any of its other subsidiaries. Borrowings under theserenewed the revolving loan facilities, bear interest at the one month LIBOR rate plus 250 basis points.which now mature June 1, 2018. Neither One Earth nor NuGen had outstanding borrowings on the revolving loans during the ninesix months ended OctoberJuly 31, 2016. One Earth2017 and NuGen are also subject to certain financial covenants under the revolving loan facilities, including working capital requirements, should they borrow on the loans.2016.

 

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 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

14

derivative financial instruments for which a lack of marketplace quotations would require the use of fair value estimation techniques.

15

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):

 

 Asset Derivatives
Fair Value
 Liability Derivatives
Fair Value
 Asset Derivatives
Fair Value
 Liability Derivatives
Fair Value
 
 October 31, 2016 January 31, 2016 October 31, 2016 January 31, 2016  July 31,
2017
 January 31,
2017
 July 31,
2017
 January 31,
2017
 
                         
Commodity futures (1) $87  $  $  $  $136  $45  $-  $- 
Forward purchase contracts (2) $  $  $408  $312   237   163   158   136 
Total $373  $208  $158  $136 

 

(1) Commodity futures are included in other prepaid expenseexpenses and other current assets. These futures contracts are short/sell positions for approximately 0.31.9 million and 0.7 million bushels of corn at OctoberJuly 31, 2016.2017 and January 31, 2017, respectively.

(2) Forward purchase contracts assets are included in prepaid expenses and other current assets while forward purchase contracts liabilities are included in accrued expenses and other current liabilities. These contracts are for purchases of approximately 4.510.3 million and approximately 0.75.3 million bushels of corn at OctoberJuly 31, 20162017 and January 31, 2016,2017, respectively.

 

As of OctoberJuly 31, 2016,2017, 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 amounts owed or owing with the same counterparty. As of OctoberJuly 31, 2016,2017, 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. As of OctoberJuly 31, 2016,2017, the Company was required to maintain collateral with the counterparty in the amount of approximately $46,000$379,000 to secure the Company’s derivative liability position.

 

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

 

Gains of approximately $115,000 and $108,000 for the third quarters of fiscal years 2016 and 2015, respectively, on the Company’s derivative financial instruments of approximately $853,000 and $1,136,000 for the second quarters of fiscal years 2017 and 2016, respectively, were included in cost of sales on the Consolidated Condensed Statements of Operations. Gains of approximately $1,740,000 and $184,000 for the first nine months of fiscal years 2016 and 2015, respectively, on the Company’s derivative financial instruments of approximately $977,000 and $1,625,000 for the first six months of fiscal years 2017 and 2016, respectively, were included in cost of sales on the Consolidated Condensed Statements of Operations.

1615

Note 10.Investments

 

The following table summarizes the Company’s equity method investment at OctoberJuly 31, 20162017 and January 31, 20162017 (dollars in thousands):

 

Entity Ownership
Percentage
  Carrying Amount
October 31, 2016
  Carrying Amount
January 31, 2016
 
             
Big River  9.7% $37,954  $38,707 

The following table summarizes income recognized from equity method investments for the periods presented (dollars in thousands):

  Three Months Ended
October 31,
  Nine Months Ended
October 31,
 
  2016  2015  2016  2015 
                 
Big River $1,838  $1,314  $3,257  $4,910 
Patriot (sold June 1, 2015)           2,947 
Total $1,838  $1,314  $3,257  $7,857 
Entity Ownership
Percentage
 Carrying Amount
July 31, 2017
 Carrying Amount
January 31, 2017
       
Big River 9.7% $36,665 $37,833

 

Undistributed earnings of the Company’s equity method investee totaled approximately $17.9$16.6 million and $18.7$17.8 million at OctoberJuly 31, 20162017 and January 31, 2016,2017, respectively. DuringThe Company received dividends from its equity method investee of approximately $2.0 million and $1.5 million during the first ninesix months of fiscal years 20162017 and 2015, the Company received dividends from equity method investees of approximately $4.0 million and $7.6 million,2016, respectively.

 

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

 

  Three Months Ended
October 31, 2016
  Three Months Ended
October 31, 2015
 
  Patriot (1)  Big River  Patriot (1)  Big River 
                 
Net sales and revenue $  $216,505  $  $215,902 
Gross profit $  $26,191  $  $22,078 
Income from continuing operations $  $18,934  $  $13,540 
Net income $  $18,934  $  $13,540 
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  Nine Months Ended
October 31, 2016
  Nine Months Ended
October 31, 2015
 
  Patriot (1)  Big River  Patriot (1)  Big River 
                 
Net sales and revenue $  $611,050  $115,614  $623,900 
Gross profit $  $49,119  $14,424  $71,345 
Income from continuing operations $  $33,555  $11,100  $50,580 
Net income $  $33,555  $11,100  $50,580 

(1)The Company’s equity interest in Patriot was sold June 1, 2015; therefore results are for the five month period ended May 31, 2015.
  Three Months Ended
July 31,
  Six Months Ended
July 31,
 
  2017  2016  2017  2016 
             
Net sales and revenue $212,070  $210,974  $404,569  $394,545 
Gross profit $11,582  $17,057  $19,764  $22,928 
Income from continuing operations $1,411  $12,216  $8,618  $14,620 
Net income $1,411  $12,216  $8,618  $14,620 

 

Big River has debt agreements that limit amounts Big River can pay in the form of dividends or advances to owners. The restricted net assets of Big River at OctoberJuly 31, 20162017 and January 31, 20162017 are approximately $298.9$279.5 million and $306.3$278.7 million, respectively.

 

On June 1, 2015, Patriot Holdings, LLC (“Patriot”) and a subsidiary of CHS Inc. (“CHS”) completed a merger that resulted in CHS acquiring 100% of the ownership interest in Patriot. During fiscal year 2015, the Company received a cash payment of approximately $45.5 million at the closing, representing its proportionate share of the merger consideration for its 27% ownership interest. The total merger consideration was approximately $196 million in cash subject to certain adjustments and certain escrow holdbacks. In connection with this transaction, the Company recognized a gain of approximately $10.4 million during the second quarter of fiscal year 2015. During the first quarter of fiscal year 2016, the Company received proceeds of approximately $2.3 million as partial payment for certain escrow holdbacks and adjustments to the purchase price. As a result, the Company recognized approximately $0.2 million as gain on sale of investment during the first quarter of fiscal year 2016. At October 31, 2016, the Company has approximately $2.3 million (recognized as gain in fiscal year 2015) in accounts receivable on the accompanying Consolidated Condensed Balance Sheet related to estimated escrow proceeds that were recognized as income. The Company expects that a determinationdoes not expect any further proceeds or gain/loss on sale of the final payment of escrowed proceedsinvestment to be received will occur by December 1, 2016.significant.

 

Note 1111.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

16

appreciation rights tied to the value of common stock, restricted stock, and restricted stock unit awards to eligible employees, non-employee directors and consultants. The Company measures share-based compensation grants at fair value on the grant date, adjusted for estimated forfeitures. The Company records noncash compensation expense related to liability and equity awards in its consolidated financial statements over the requisite service period on a straight-line basis. At July 31, 2017, 511,174 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 date of the grant. 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.

At July 31, and January 31, 2017, unrecognized compensation cost related to nonvested restricted stock was approximately $321,000 and $214,000, respectively. The following table summarizes non-vested restricted stock award activity for the six months ended July 31, 2017 and 2016:

  Six Months Ended July 31, 2017 
    
  Non-Vested
Shares
  Weighted
Average Grant
Date Fair Value
(000’s)
  Weighted
Average Remaining
Vesting Term
(in years)
 
          
Non-Vested at January 31, 2017  23,350  $1,386   2 
Granted  14,156   1,370     
Forfeited  -   -     
Vested  8,091   481     
             
Non-Vested at July 31, 2017  29,415  $2,275   2 
    
  Six Months Ended July 31, 2016 
    
  Non-Vested
Shares
  Weighted
Average Grant
Date Fair Value
(000’s)
  Weighted
Average Remaining
Vesting Term
(in years)
 
          
Non-Vested at January 31, 2016  3,168  $200   2 
Granted  21,502   1,269     
Forfeited  -   -     
Vested  1,320   83     
             
Non-Vested at July 31, 2016  23,350  $1,386   3 

Note 12. Income Taxes

The effective tax rate on consolidated pre-tax income was 35.6% and 33.3% for the three months ended OctoberJuly 31, 2017 and 2016, and 14.8% for the three months ended October 31, 2015.respectively. The effective tax rate on consolidated pre-tax income was 32.9%

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32.4% and 32.6% for the ninesix months ended OctoberJuly 31, 2017 and 2016, and 28.1% for the nine months ended October 31, 2015.respectively. The fluctuation in the effective tax rate primarily relates to the releaseimpact of valuation allowances against capital loss carryforwards, the domestic production activities deduction, a change in the apportionment of income to certain states, the expiration of statutes for years with uncertain tax positions and a decrease in state income tax rates. These items reducednoncontrolling interests. The Company expects the effective tax rate, approximately 17% for the quarter ended October 31, 2015 and approximately 7% forremainder of fiscal year 2017, to be significantly lower than the nine months ended October 31, 2015. The provision for uncertaincurrent year to date levels as the Company expects to earn federal income tax positions increased the effective tax rate approximately 1.9% and 1.4% for the quarter and nine months ended October 31, 2016, respectively.credits from its refined coal operation (see Note 16).

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The Company files a U.S. federal income tax return and various state income tax returns in various states.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, 2010 and prior. A reconciliation of the beginning and ending

amount of unrecognized tax benefits, including interest and penalties, is as follows (amounts in thousands):

 

Unrecognized tax benefits, January 31, 2016 $987 
 Six Months Ended
July 31,
 
 2017 2016 
     
Unrecognized tax benefits, beginning of period $2,096  $987 
Changes for prior years’ tax positions  749   164   171 
Changes for current year tax positions  491   -   - 
Unrecognized tax benefits, October 31, 2016 $2,227 
Unrecognized tax benefits, end of period $2,260  $1,158 

 

Note 12.13.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 7.611.4 million bushels of corn, the principal raw material for their ethanol plants. They expect to take delivery of the grain through FebruaryOctober 2017.

 

One Earth and NuGen have combined sales commitments for approximately 29.667.8 million gallons of ethanol, approximately 94,00079,000 tons of distillers grains and approximately 12.311.7 million pounds of non-food grade corn oil. They expect to deliver the ethanol, distillers grains and non-food grade corn oil through JanuaryDecember 2017.

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Note 13.14.Net Sales and Revenue

 

The following table summarizes sales for each product and service group for the periods presented (amounts in thousands):

 

 Three Months Ended Nine Months Ended 
 October 31, October 31,  Three Months Ended
July 31,
 Six Months Ended
July 31,
 
Product or Service Category 2016 2015 2016 2015  2017 2016 2017 2016 
         
Ethanol $90,702  $82,767  $259,266  $248,329  $88,785  $90,933  $180,257  $168,564 
Dried distillers grains  19,551   22,518   55,551   64,354   13,472   18,946   28,622   36,000 
Non-food grade corn oil  5,074   3,994   13,658   12,002   4,726   4,738   9,318   8,584 
Modified distillers grains  853   1,108   3,400   4,109   1,748   983   3,667   2,547 
Other  103   197   337   467   13   107   23   234 
Total $116,283  $110,584  $332,212  $329,261  $108,744  $115,707  $221,887  $215,929 

 

Note 14.15.Related-Party Transactions

 

During the thirdsecond quarters of fiscal year 20162017 and 2015,2016, One Earth and NuGen purchased approximately $34.2$36.5 million and approximately $38.1$36.0 million, respectively, of corn from minority equity

19

investors and board members of those subsidiaries. Such purchases totaled approximately $114.6$78.7 million and approximately $114.4$80.4 million for the ninesix months ended OctoberJuly 31, 2017 and 2016, respectively. The Company had amounts payable to related parties for corn purchases of approximately $1.6 million and 2015,$1.7 million at July 31, 2017 and January 31, 2017, respectively.

 

Note 16. Subsequent Event

On August 10, 2017, the Company, through a 95.35% owned subsidiary, purchased the entire ownership interest of a refined coal facility for approximately $12 million in cash. The facility is in operation and will begin affecting the Company’s financial results during the third quarter of fiscal year 2017. The Company expects that the revenues from the sale of refined coal produced in the facility will be subsidized by federal production tax credits, subject to meeting qualified emissions reductions as governed by Section 45 of the Internal Revenue Code.

The impact on the combined results of operations of the Company and the refined coal facility, on a pro forma basis, as though the companies had been combined as of the beginning of fiscal year 2017 is insignificant as the refined coal facility has been inactive for several years up until the Company’s acquisition.

The Company expects to complete its analysis of transaction costs related to the acquisition of the refined coal facility and the estimated fair value of assets acquired and liabilities assumed during the third quarter of fiscal year 2017.

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

 

At OctoberJuly 31, 2016,2017, we had 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:

 

EntityTrailing 12
Months
Ethanol
Gallons
Shipped
REX’s
Current
Effective
Ownership
Interest
REX’s
Current
Effective
Ownership
Interest
Current Effective
Ownership of
Trailing 12
Months Ethanol
Gallons Shipped
One Earth Energy, LLC119.1120.5 M75.0%75.0%89.390.4 M
NuGen Energy, LLC124.5131.4 M99.5%99.5%123.9130.7 M
Big River Resources, LLC:   
Big River Resources W Burlington, LLC107.1 M9.7%9.7%10.4 M
Big River Resources Galva, LLC126.1123.7 M9.7%9.7%12.212.0 M
Big River United Energy, LLC126.9129.2 M5.4%5.4%6.97.0 M
Big River Resources Boyceville, LLC57.657.2 M9.7%9.7%5.65.5 M
Total661.3669.1 M 248.3256.0 M

 

Our ethanol operations are highly dependent on commodity prices, especially prices for corn, ethanol, distillers grains, non-food grade corn oil and natural gas. 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 a number of factors that affect commodity prices in general, including crop conditions, 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 can impact ethanol prices), at times ethanol prices may lag 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 marginally 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 2.8)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 also expect our ethanol plants to produce approximately 15.5 pounds of distillers grains and 0.7 pounds of non-food grade corn oil for each bushel of grain processed.

 

We attempt to manage the risk related to the volatility of commodity prices by utilizing forward grain purchase and 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

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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

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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 the 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.

 

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.

 

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 may also fund, through loans, all costs relating to new intellectual property, consultants, and future research and development, pilot field tests and equipment purchases for commercialization stage of the patents. WeTo date, we have paid approximately $1,724,000$1.8 million cumulatively including $113,000 in fiscal year 2016 for our ownership interest, patent and other expenses. We have not tested or proven the commercial feasibility of the technology.

 

Critical Accounting Policies and Estimates

 

During the three months ended OctoberJuly 31, 2016,2017, we did not change any of our critical accounting policies as disclosed in our 20152016 Annual Report on Form 10-K as filed with the Securities and Exchange Commission on March 25, 2016. All other accounting policies used in preparing our interim fiscal year 2016 Consolidated Condensed Financial Statements are the same as those described in our Form 10-K.27, 2017.

 

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 2016”2017” means the period February 1, 20162017 to January 31, 2017.2018.

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Results of Operations

 

Comparison of Three and NineSix Months Ended OctoberJuly 31, 20162017 and 20152016

 

The following table summarizes selected data from our consolidated operations for the periods presented:

 

 Three Months Ended Nine Months Ended 
 October 31, October 31,  Three Months Ended
July 31,
 Six Months Ended
July 31,
 
 2016 2015 2016 2015  2017 2016 2017 2016 
                  
Average selling price per gallon of ethanol $1.44  $1.44  $1.42  $1.45  $1.45  $1.49  $1.45  $1.41 
Gallons of ethanol sold (in millions)  62.8   57.3   182.5   171.0   61.3   60.9   124.7   119.7 
Average selling price per ton of dried distillers grains $122.34  $146.64  $127.27  $152.69  $95.39  $134.81  $97.81  $130.12 
Tons of dried distillers grains sold  159,812   153,560   436,474   421,461   141,233   140,541   292,635   276,662 
Average selling price per pound of non-food grade corn oil $0.29  $0.26  $0.27  $0.27  $0.29  $0.29  $0.28  $0.27 
Pounds of non-food grade corn oil sold (in millions)  17.6   15.4   49.7   43.8   16.5   16.4   33.1   32.2 
Average selling price per ton of modified distillers grains $45.17  $56.40  $54.49  $70.99  $41.00  $56.60  $41.47  $58.54 
Tons of modified distillers grains sold  18,876   19,645   62,393   57,891   42,632   17,370   88,434   43,517 
Average cost per bushel of grain $3.30  $3.62  $3.51  $3.64  $3.38  $3.73  $3.47  $3.63 
Average cost of natural gas (per mmbtu) $3.31  $3.21  $3.08  $3.82  $3.30  $2.71  $3.52  $2.96 

 

Net sales and revenue in the quarter ended OctoberJuly 31, 20162017 were approximately $116.3$108.7 million compared to approximately $110.6$115.7 million in the prior year’s thirdsecond quarter, representing an increasea decrease of approximately $5.7$7.0 million. Net sales and revenue in the first ninesix months of fiscal year 20162017 were approximately $332.2$221.9 million compared to approximately $329.3$215.9 million in the in the first ninesix months of fiscal year 2015,2016, representing an increase of approximately $2.9$6.0 million.

The following table summarizes sales of our consolidated operations for each major product and service group for the periods presented (amounts in thousands):

 

 Three Months Ended Nine Months Ended 
 October 31, October 31,  Three Months Ended
July 31,
 Six Months Ended
July 31,
 
Product Category 2016 2015 2016 2015  2017 2016 2017 2016 
                  
Ethanol $90,702  $82,767  $259,266  $248,329  $88,785  $90,933  $180,257  $168,564 
Dried distillers grains  19,551   22,518   55,551   64,354   13,472   18,946   28,622   36,000 
Non-food grade corn oil  5,074   3,994   13,658   12,002   4,726   4,738   9,318   8,584 
Modified distillers grains  853   1,108   3,400   4,109   1,748   983   3,667   2,547 
Other  103   197   337   467   13   107   23   234 
Total $116,283  $110,584  $332,212  $329,261  $108,744  $115,707  $221,887  $215,929 
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Ethanol sales increaseddecreased from approximately $82.8$90.9 million in the third quarter of fiscal year 2015 to approximately $90.7 million in the thirdsecond quarter of fiscal year 2016 to approximately $88.8 million in the second quarter of fiscal year 2017, primarily a result of an increase of 5.5 million gallonsa $0.04 decrease in the price per gallon sold. Dried distillers grains sales decreased from approximately $22.5$18.9 million in the third quarter of fiscal year 2015 to approximately $19.6 million in the thirdsecond quarter of fiscal year 2016 to approximately $13.5 million in the second quarter of fiscal year 2017, primarily a result of a $24.30$39.42 decline in the price per ton sold. The decline in selling price was partially offset by a 4% increase in tons sold. Management believes the decline in the selling price results primarily from the ongoing uncertainty of Chinese imports of domestic dried distillers grains as the China Ministry of Commerce had announced an anti-dumping and countervailing duty investigation in January 2016 and has imposed an anti-dumping tariff and a countervailing duty on U.S. dried distillers grains exports to China. In a final ruling in January 2017, China that total approximately 45%increased the dried distillers grains anti-dumping duty to a range of 42.2% up to 53.7% and the dried distillers grains countervailing duty to a range of 11.2% up to 12.0%. In addition, Vietnam suspended imports of U.S dried distillers grains and this has also contributed to the decline in DDG prices. Non-food grade corn oil sales increased from approximately $4.0 million in the thirdsecond quarter of fiscal year 2015 to2017 were consistent with sales in the second quarter of fiscal year 2016. Modified distillers grains sales increased from approximately $5.1$1.0 million in the thirdsecond quarter of fiscal year 2016 to approximately $1.7 million in the second quarter of fiscal year 2017, primarily a result of a 14%145% increase in pounds sold. Modified distillers grains sales decreased from approximately $1.1 million in the third quartertons sold which was partially offset by a decline of fiscal year 2015 to approximately $0.9 million in the third quarter of fiscal year 2016, primarily a result of a $11.23 decline$15.60 in the price per ton sold.

 

Ethanol sales increased from approximately $248.3$168.6 million in the first ninesix months of fiscal year 20152016 to approximately $259.3$180.3 million in the first ninesix months of fiscal year 2016,2017, primarily a result of an increase of 11.55.0 million gallons sold. The volumesold and a $0.04 increase was partially offset by a $0.03 decline in the price per gallon sold. Dried distillers grains sales decreased from approximately $64.4$36.0 million in the first nine months of fiscal year 2015 to approximately $55.6 million in the first ninesix months of fiscal year 2016 to approximately $28.6 million in the first six months of fiscal year 2017, primarily a result of a $25.42$32.31 decline in the price per ton sold. The decline in selling price was partially offset by a 4%6% increase in tons sold. Management believes the decline in the selling price results primarily from the ongoing uncertainty of Chinese imports of domestic dried distillers grains discussed above.same reasons as described in the preceding paragraph. Non-food grade corn oil sales increased from approximately $12.0$8.6 million in the first nine months of fiscal year 2015 to approximately $13.7 million in the first ninesix months of fiscal year 2016 to approximately $9.3 million in the first six months of fiscal year 2017, primarily a result of slight increases in the price per pound sold and quantities sold. Modified distillers grains sales increased from approximately $2.5 million in the first six months of fiscal year 2016 to approximately $3.7 million in the first six months of fiscal year 2017, primarily a result of a 13%103% increase in pounds sold. Modified distillers grains sales decreased from approximately $4.1 million in the first nine monthstons sold which was partially offset by a decline of fiscal year 2015 to approximately $3.4 million in the first nine months of fiscal year 2016 primarily a result of a $16.50 decline$17.07 in the price per ton sold.

 

We expect that sales in future periods will be based upon the following (One Earth and NuGen only):

 

ProductAnnual Sales Quantity
  
Ethanol240260 million to 260280 million gallons
Dried distillers grains580,000590,000 to 620,000 tons
Non-food grade corn oil65 million to 7580 million pounds
Modified distillers grains70,000170,000 to 90,000200,000 tons

 

This expectation assumes that One Earth and NuGen will continue to operate at or nearabove historical production levels, which is dependent upon the crush spread realized. NuGen has received the EPA pathway approval and has permits to increase its production levels to 150 million gallons annually. One Earth has received the EPA pathway approval and has permits to increase its production levels to 131

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million gallons annually. We are working on debottlenecking the plants and plan to increase production levels over time dependent on industry conditions, plant profitability and plant profitability.the completion of capacity expansion projects. We may vary the amounts of dried and modified distillers grains production, and resulting sales, based upon market conditions.

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Gross profit for the thirdsecond quarter of fiscal year 20162017 was approximately $20.2$10.8 million (17.3%(9.9% of net sales and revenue) which was approximately $5.9$6.5 million higherlower compared to approximately $14.3$17.3 million of gross profit (12.9%(14.9% of net sales and revenue) for the thirdsecond quarter of fiscal year 2015.2016. The crush spread for the thirdsecond quarter of fiscal year 20162017 was approximately $0.31$0.24 per gallon of ethanol sold compared to the thirdsecond quarter of fiscal year 20152016 which was approximately $0.19$0.20 per gallon of ethanol sold. The decline of approximately $3.0$5.5 million in sales of dried distillers graingrains compared to the thirdsecond quarter of fiscal year 20152016 negatively affected gross profit. Management believes this decline results primarily from the continued uncertainty regarding future Chinese and Vietnamese imports of domesticU. S produced distillers grains. Grain accounted for approximately 75% ($72.573.2 million) of our cost of sales during the thirdsecond quarter of fiscal year 20162017 compared to approximately 77%79% ($73.677.6 million) during the thirdsecond quarter of fiscal year 2015.2016. Natural gas accounted for approximately 6%5% ($5.3 million) of our cost of sales during the thirdsecond quarter of fiscal year 20162017 compared to approximately 5%4% ($4.94.2 million) during the thirdsecond quarter of fiscal year 2015.2016. Plant related repairs and maintenance expense was approximately $2.0 million higher in the second quarter of fiscal year 2017 compared to the second quarter of fiscal year 2016.

 

Gross profit for the first ninesix months of fiscal year 20162017 was approximately $45.9$23.3 million (13.8%(10.5% of net sales and revenue) which was approximately $4.2$2.4 million higherlower compared to approximately $41.7$25.7 million of gross profit (12.7%(11.9% of net sales and revenue) for the first ninesix months of fiscal year 2015.2016. The crush spread for the first ninesix months of fiscal year 20162017 was approximately $0.20$0.23 per gallon of ethanol sold compared to approximately $0.18$0.16 per gallon of ethanol sold during the first ninesix months of fiscal year 2015.2016. The decline of approximately $7.4 million in sales of dried distillers grain compared to the first six months of fiscal year 2016 negatively affected gross profit. Grain accounted for approximately 77%76% ($221.3150.9 million) of our cost of sales during the first ninesix months of fiscal year 20162017 compared to approximately 76%78% ($218.1148.7 million) during the first ninesix months of fiscal year 2015.2016. Natural gas accounted for approximately 5%6% ($14.411.3 million) of our cost of sales during the first ninesix months of fiscal year 20162017 compared to approximately 6%5% ($17.59.1 million) during the first ninesix months of fiscal year 2015.2016. Given the inherent volatility in ethanol, distillers grains, non-food grade corn oil, grain and natural gas prices, we cannot predict the likelihood that the spread between ethanol, distillers grains, non-food grade corn oil and grain prices in future periods will be consistent compared to historical periods. Plant related repairs and maintenance expense was approximately $1.6 million higher in the first six months of fiscal year 2017 compared to the first six months of fiscal year 2016. We expect gross profit, in future periods, to be negatively impacted by our refined coal operation (see Note 16) as the refined coal operation is expected to generate a pre-tax operating loss.

 

We attempt to match quantities of ethanol, distillers grains and non-food grade corn oil sale contracts with an appropriate quantity of grain purchase contracts over a given period of time 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

24

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 the crush spread for more than four months. Based on existing contracts at the end of the thirdsecond quarter of fiscal year 2016, approximately 2%2017, none of our forecasted ethanol, approximately 14%10% of our forecasted distillers grains and approximately 17%15% of our forecasted non-food grade corn oil production during the next 12 months have been sold under fixed-price contracts. The effect of a 10% adverse change in the price of ethanol, distillers grains and non-food grade corn oil from the current pricing would result in a decrease in annual revenues of approximately $45.4$48.4 million for the remaining forecasted sales. Similarly, approximately 1% of our estimated corn usage for the next 12 months was subject to fixed-price contracts. The effect of a 10% adverse change in the price of corn from the current pricing would result in an increase in annual cost of goods sold of approximately $29.1$34.2 million for the remaining forecasted grain purchases. Approximately 3%2% of our estimated natural gas usage for the next 12 months was subject to fixed-price contracts. The effect of a 10% adverse change in the price of natural gas from the current pricing would

24

result in an increase in annual cost of goods sold of approximately $2.0 million for the remaining forecasted natural gas purchases.

 

Selling, general and administrative expenses for the thirdsecond quarter of fiscal year 2017 were consistent with the second quarter of fiscal year 2016 amount. Such expenses were approximately $5.1$10.2 million for the first six months of fiscal year 2017 compared to approximately $4.7$9.2 million for the third quarterfirst six months of fiscal year 2015.2016. The quarterly increase is primarily related to higher incentive compensation which is consistent with the higher profitability in the third quarterrail car lease charges as our fleet of fiscal year 2016 compared to the third quarter of fiscal year 2015. Selling, generalrail cars ages and administrative expenses for the first nine months of fiscal year 2016 were approximately $14.3 million, compared to approximately $15.6 million for the first nine months of fiscal year 2015. The year to date decrease is primarily related to lower incentive compensation which is consistent with the lower profitability in the first nine months of fiscal year 2016 compared to the first nine months of fiscal year 2015. Lower professional fees in fiscal year 2016 also contributed to the decline in year over year expenses.requires more repairs. We expect selling, general and administrative expenses to remain consistent with fiscal year 20152016 results in future periods, with the exception of variability of incentive compensation which is based upon Company profitability.

 

During the thirdsecond quarters of fiscal years 20162017 and 2015,2016, we recognized income of approximately $1.8$0.1 million and $1.3$1.2 million, respectively, from our equity investment. DuringSuch income was approximately $0.8 million and $1.4 million during the first ninesix months of fiscal yearsyear 2017 and 2016, and 2015, we recognized income of approximately $3.3 million and $7.9 million, respectively, from our equity investment. Effective June 1, 2015, a merger between Patriot and CHS occurred in which our ownership interest in Patriot was sold; thus we ceased recording income from Patriot using the equity method of accounting.respectively. Big River has interests in four ethanol production plants and has an effective ownership of ethanol gallons shipped in the trailing twelve months ended OctoberJuly 31, 20162017 of approximately 355353 million gallons. Big River’s results in fiscal year 20162017 have been negatively impacted from commodity pricing and related hedging activities.by an asset impairment charge which reduced our equity method income by approximately $0.5 million. Due to the inherent volatility of commodity prices within the crush spread,ethanol industry, we cannot predict the likelihood of future operating results from Big River being similar to historical results.

 

On June 1, 2015 Patriot and a subsidiary of CHS Inc. (“CHS”) completed a merger that resulted in CHS acquiring 100% of the ownership interest in Patriot. During the first quarter of fiscal year 2016, we received proceeds of approximately $2.3 million as partial payment for certain escrow holdbacks and adjustments to the purchase price related to the merger between Patriot and CHS. As a result, we recognized approximately $0.2 million as gain on sale of investment during the first quarter of fiscal year 2016. At October 31, 2016, we have approximately $2.3 million in accounts receivableWe do not expect any further proceeds or gain/loss on the accompanying Consolidated Condensed Balance Sheet related to estimated escrow proceeds that were previously recognized as income. We expect that a determinationsale of the final payment of escrowed proceedsinvestment to be received will occur by December 31, 2016.

On June 1, 2015, Patriot and a subsidiary of CHS completed a merger that resulted in CHS acquiring 100% of the ownership interest in Patriot. We received a cash payment of approximately $45.5 million at the closing, representing our proportionate share of the merger proceeds. The total merger consideration was approximately $196 million in cash subject to certain adjustments and certain escrow holdbacks. In connection with this transaction, we recognized a gain of approximately $10.4 million during the second quarter of fiscal year 2015.significant.

 

Gain on disposal of property and equipment was insignificant for bothof approximately $0.2 million during the third quarterssecond quarter and first ninesix months of fiscal yearsyear 2016 and 2015. We expect gain on disposal of property and equipmentrelate to be insignificant fortwo real estate properties sold. No such properties were sold during the remainderfirst six months of fiscal year 2016.2017.

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Interest and other income was insignificantapproximately $0.3 million for both the third quarterssecond quarter of fiscal year 2017 versus approximately $0.1 million for the second quarter of fiscal year 2016. Interest and other income was approximately $0.5 million for the first ninesix months of fiscal years 2016 and 2015. We expect interest and other income to remain consistent withyear 2017 versus approximately $0.3 million for the first six months of fiscal year 2015 levels for the remainder of2016. The income has increased as yields on our excess cash have improved compared to fiscal year 2016.

 

As a result of the foregoing, income before income taxes was approximately $17.2$6.5 million for the thirdsecond quarter of fiscal year 20162017 versus approximately $11.1$13.5 million for the thirdsecond quarter of fiscal year 2015.2016. Income before income taxes was approximately $35.7$14.5 million for the first ninesix months of fiscal year 20162017 versus approximately $45.3$18.5 million for the first ninesix months of fiscal year 2015.2016.

 

Our effective tax rate was 33.3%approximately 35.6% and 14.8%33.3% for the thirdsecond quarters of fiscal years 20162017 and 2015,2016, respectively, and 32.9%32.4% and 28.1%32.6% for the first ninesix months of fiscal years 20162017 and 2015, respectively. The fluctuation in the effective tax rate primarily relates to the release of valuation allowances against capital loss carryforwards, the domestic production activities deduction, a change in the apportionment of income to certain states, the expiration of statutes for years with uncertain tax positions and a decrease in state income tax rates. These items reduced the effective tax rate approximately 17% for the quarter ended October 31, 2015 and approximately 7% for the nine months ended October 31, 2015. The provision for uncertain tax positions increased the effective tax rate approximately 1.9% and 1.4% for the quarter and nine months ended October 31, 2016, respectively. We expect our effective tax rate, for the remainder of fiscal year 2017, to approximate 30-35% (gross of noncontrolling interests) in future periods.be significantly lower than the current year to date levels as we expect to earn federal income tax credits from our refined coal operation (see Note 16).

 

As a result of the foregoing, net income was approximately $11.5$4.2 million for the thirdsecond quarter of fiscal year 2016 versus2017 compared to approximately $9.4$9.0 million for the thirdsecond quarter of fiscal year 2015.2016. Net income was approximately $24.0$9.8 million for the ninefirst six months of fiscal year 2016 versus2017 compared to approximately $32.6$12.5 million for the first ninesix months of fiscal year 2015.2016.

 

Income related to noncontrolling interests was approximately $2.5$1.2 million and approximately $2.0$0.9 million during the thirdsecond quarters of fiscal years 20162017 and 2015,2016, respectively, and was approximately $4.0$2.3 million and approximately $4.8$1.5 million during the first ninesix months of fiscal years 2017 and 2016, and 2015, respectively. These amountsrepresent the owners’ (other than us) share of the income or loss of NuGen, One Earth and Future Energy.

 

As a result of the foregoing, net income attributable to REX common shareholders for the thirdsecond quarter of fiscal year 20162017 wasapproximately $8.9 $2.9 million, an increasea decrease of approximately $1.4$5.3 million fromapproximately $7.5 $8.2 million for the thirdsecond quarter of fiscal year 2015.2016. Net income attributable to REX common shareholders for the first ninesix months of fiscal year 20162017 wasapproximately $20.0 $7.5 million, a decrease of approximately $7.8$3.5 million fromapproximately $27.8 $11.0 million for the first ninesix months of fiscal year 2015.2016. The decrease from the year to date fiscal year 2015 period2016 results is primarily relatesrelated to the sale of Patriot in fiscal year 2015reduced dried distillers grains pricing, increased natural gas costs and the inclusion of five months of income in fiscal year 2015 using the equity method of accounting for our investment in Patriot.increased repairs and maintenance expenditures.

26

Liquidity and Capital Resources

 

Net cash provided by operating activities was approximately $41.4$13.5 million for the first ninesix months of fiscal year 2016,2017, compared to approximately $21.8$11.4 million for the first ninesix months of fiscal year 2015.2016. For the first ninesix months of fiscal year 2017, cash was provided by net income of approximately $9.8 million, adjusted for non-cash items of approximately $10.0 million, which consisted of depreciation and amortization, income from equity method investments, the deferred income tax provision and stock based compensation expense. Big River paid dividends to REX of approximately $2.0 million during the first six months of fiscal year 2017. A decrease in the balance of accounts receivable provided cash of approximately $0.9 million, which was primarily a result of the timing of customer shipments and

26

payments. An increase in the balance of inventories used cash of approximately $5.0 million, which was primarily a result of the timing of receipt of raw materials as we took advantage of purchasing opportunities that existed during the first six months of fiscal year 2017. An increase in the balance of other assets used cash of approximately $1.0 million, which was primarily a result of income tax payments and normal variations in various asset balances. 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. A decrease in the balance of other current liabilities used cash of approximately $4.8 million which was primarily a result of payments of incentive compensation and real estate taxes.

Net cash provided by operating activities was approximately $11.4 million for the first six months of fiscal year 2016. For the first six months of fiscal year 2016, cash was provided by net income of approximately $24.0$12.5 million, adjusted for non-cash items of approximately $9.7$8.0 million, which consisted of depreciation and amortization, income from equity method investments, gain on disposal of real estate and property and equipment, net, gain on sale of investment and the deferred income tax provision.stock based compensation expense. We received dividends from Big River of approximately $4.0$1.5 million during the first ninesix months of fiscal year 2016. An increase in the balance of accounts receivable used cash of approximately $1.7$4.3 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 $2.3$6.5 million, which was primarily a result of the timing of receipt of raw materials as we took advantage of purchasing opportunities that existed during the thirdsecond quarter of fiscal year 2016. A decrease in the balance of other assets provided cash of approximately $2.8$3.0 million, as prior year overpayments of income taxes were usedmore than sufficient to reduceoffset estimates of our current year liabilities. An increaseA decrease in the balance of accounts payable providedused cash of approximately $1.7$3.1 million, which was primarily a result of the timing of inventory receipts and vendor payments. An increase in the balance of other current liabilities provided cash of approximately $3.2 million which was primarily a result of higher accruals for our income tax provision.

Net cash provided by operating activities was approximately $21.8 million for the first nine months of fiscal year 2015. For the first nine months of fiscal year 2015, cash was provided by net income of approximately $32.6 million, adjusted for non-cash items of approximately ($12.6) million, which consisted of depreciation, impairment charges and amortization, income from equity method investments, gain on sale of investment and gain on disposal of real estate and property and equipment and the deferred income tax provision. Dividends received from our equity method investees were approximately $7.6 million in the first nine months of fiscal year 2015. An increase in the balance of accounts receivable used cash of approximately $2.3 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 $5.5 million, which was primarily a result of the timing of receipt of raw materials. An increase in the balance of accounts payable provided cash of approximately $4.9 million, which was primarily a result of the timing of inventory receipts and vendor payments. Other liabilities decreased approximately $2.8 million, which was primarily a result of the payments of accrued payroll and incentive compensation balances.

 

At OctoberJuly 31, 2016,2017, working capital was approximately $183.9$209.8 million, compared to approximately $159.7$204.0 million at January 31, 2016.2017. The ratio of current assets to current liabilities was 9.412.2 to 1 at OctoberJuly 31, 20162017 and 9.110.1 to 1 at January 31, 2016.2017.

 

Cash of approximately $7.6$14.4 million was used in investing activities for the first ninesix months of fiscal year 2016,2017, compared to cash provided of approximately $37.8$5.7 million during the first ninesix months of fiscal year 2015.2016. During the first ninesix months of fiscal year 2017, we had capital expenditures of approximately $14.4 million, the majority of which was plant capacity expansion projects at the One Earth and NuGen ethanol plants. We expect to spend between $5.0 million and $7.0 million during the remainder of fiscal year 2017 on various capital projects.

Cash of approximately $5.7 million was used in investing activities for the first six months of fiscal year 2016. During the first six months of fiscal year 2016, we had capital expenditures of approximately $11.8$9.3 million, primarily related to improvements at the One Earth and NuGen ethanol plants. We expect to spend between $2.0 million and $3.0 million during the remainder of fiscal year 2016 on various capital projects. During the first ninesix months of fiscal year 2016, we received approximately $2.3 million as partial payment for certain escrow holdbacks and adjustments to the purchase price related

27

to the sale of our equity investment in Patriot. We received approximately $1.5$1.0 million of proceeds from the sale of threetwo real estate properties during the first ninesix months of fiscal year 2016.

 

Cash ofused in financing activities totaled approximately $37.8$1.7 million was provided by investing activities for the first ninesix months of fiscal year 2015. During2017 compared to approximately $6.8 million for the first ninesix months of fiscal year 2015, we had capital expenditures of approximately $9.9 million, primarily related to improvements at the One Earth and NuGen ethanol plants. The sale of our equity investment in Patriot provided cash of approximately $45.5 million during2016. During the first nine six

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months of fiscal year 2015. During the first nine months2017, we used cash of fiscal year 2015, we sold three real estate properties that generated approximately $1.9$1.7 million to purchase shares from and pay dividends to noncontrolling members of proceeds.One Earth.

 

Cash used in financing activities totaled approximately $6.8 million for the first ninesix months of fiscal year 2016 compared to approximately $60.7 million for the first nine months of fiscal year 2015.2016. During the first ninesix months of fiscal year 2016, we used cash of approximately $4.7 million to purchase approximately 95,000 shares of our common stock in open market transactions. During the first ninesix months of fiscal year 2016, we used cash of approximately $2.1 million to purchase shares from and pay dividends to noncontrolling members of One Earth and NuGen. We expect additional such payments of approximately $1.7 million for the remainder of fiscal year 2016. During the first nine months of fiscal year 2015, we used cash of approximately $60.1 million to purchase approximately 1,045,000 shares of our common stock in open market transactions. During the first nine months of fiscal year 2015, we used cash of approximately $0.6 million to purchase shares from noncontrolling members of One Earth.

 

We are investigating various uses of our excess cash. We have a stock buyback program, and given our current authorization level, can repurchase atotal of approximately 155,000 shares.We also plan to seek and evaluate other investment opportunities including organic plant expansion, other energy related, agricultural or other ventures we believe fit our investment criteria. On August 10, 2017 we purchased a refined coal company for approximately $12.0 million (see Note 16).

 

Effective April 1, 2016, One Earth and NuGen each entered into $10.0 million revolving loan facilities that maturematured April 1, 2017. Any borrowings will be secured by assets of One Earth or NuGen. These revolving loan facilities are recourse only to One Earth and NuGen and not to REX American Resources Corporation or anyrenewed the revolving loan facilities, which mature June 1, 2018, during the second quarter of its other subsidiaries. Borrowings under these facilities bear interest at the one month LIBOR rate plus 250 basis points.fiscal year 2017. Neither One Earth nor NuGen had outstanding borrowings on the revolving loans as of Octoberduring the six months ended July 31, 2016. One Earth and NuGen are also subject to certain financial covenants under the revolving loan facilities, including working capital requirements, should they borrow on the loans. The specific covenant requirements, descriptions and calculated ratios and amounts at October 31, 2016 are as follows:

·Maintain working capital of at least $5 million.

At October 31, 2016, working capital at One Earth and NuGen was approximately $70.4 million and $51.7 million, respectively.

One Earth and NuGen were in compliance with all covenants, as applicable, at October 31, 2016.2017.

 

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

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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, ethanol plants operating efficiently and according to forecasts and projections, changes in the 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, 20162017 (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 OctoberJuly 31, 2016,2017, One Earth and NuGen combined have forward purchase contracts for approximately 7.611.4 million bushels of corn, the principal

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raw material for their ethanol plants. One Earth and NuGen expect to take delivery of the corn through FebruaryOctober 2017. At OctoberJuly 31, 2016,2017, One Earth and NuGen have combined sales commitments for approximately 29.667.8 million gallons of ethanol, approximately 94,00079,000 tons of distillers grains and approximately 12.311.7 million pounds of non-food grade corn oil. One Earth and NuGen expect to deliver the ethanol, distillers grains and non-food grade corn oil through JanuaryDecember 2017. Approximately 2%None of our forecasted ethanol sales during the next 12 months have been sold under fixed-price contracts. As a result, the effect of a 10% adverse move in the price of ethanol from the current pricing would result in a decrease in annual revenues of approximately $37.4$40.0 million. Approximately 14%10% of our forecasted distillers grains sales during the next 12 months have been sold under fixed-price contracts. As a result, the effect of a 10% adverse move in the price of distillers grains from the current pricing would result in a decrease in annual revenues of approximately $6.4 million. Approximately 17%15% of our forecasted non-food grade corn oil sales during the next 12 months have been sold under fixed-price contracts. As a result, the effect of a 10% adverse move in the price of non-food grade corn oil from the current pricing would result in a decrease in annual revenues of approximately $1.7$1.9 million. Similarly, approximately 1% of our estimated corn usage for the next 12 months was subject to fixed-price contracts. As a result, the effect of a 10% adverse move in the price of corn from the current pricing would result in an increase in annual cost of goods sold of approximately $29.1$34.2 million. Approximately 3%2% of our estimated natural gas usage for the next 12 months was subject to fixed-price contracts. As a result, the effect of a 10% adverse move in the price of natural gas from the current pricing would result in an increase in annual cost of goods sold of approximately $2.0 million.

 

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

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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.

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Item 1A.Risk Factors

During the quarter ended OctoberJuly 31, 2016,2017, 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, 2016.2017, except as follows:

 

Risks Relating to our Refined Coal Investment

Our refined coal investments are subject to various risks and uncertainties.

We have purchased a company to produce refined coal that we believe qualifies to earn tax credits under IRC Section 45 through November 2021. Our ability to generate returns and avoid write-offs in connection with this investment is subject to various risks and uncertainties. These include, but are not limited to, the risks and uncertainties as set forth below.

Availability of the tax credits under IRC Section 45. Our ability to claim tax credits under IRC Section 45 depends upon the operation in which we have purchased satisfying certain ongoing conditions set forth in IRC Section 45. Furthermore, the tax credits could be reduced or completely eliminated as a result of changes in income tax laws and/or regulations.

The IRS could ultimately determine that the purchase of the refined coal facility and/or its operations have not satisfied, or have not continued to satisfy, the conditions set forth in IRC Section 45. Additionally, Congress could modify income tax laws and remove the tax credits retroactively. As the refined coal operation is expected to generate pre-tax losses, the unavailability of the tax credits for any reason could have a material impact on our results of operations.

IRC Section 45 phase out provisions. IRC Section 45 contains phase out provisions based upon the market price of coal, such that, if the price of coal rises to specified levels, we could lose some or all of the tax credits we expect to receive from this operation.

Business risks. The refined coal operation receives tax credits by selling its refined coal to an unrelated party. The unrelated party is not obligated to continue purchasing refined coal. If the unrelated party ceases to purchase refined coal from us, this would cause us to attempt to move our refined coal plant to a different location, which could require us to invest additional capital, or to find a different user to purchase our refined coal. In addition, we may not be able to find a suitable location to move our refined coal plant to or find a different user to purchase our refined coal in a timely manner. A reduction or cessation of refined coal sales could have a material impact on our results of operations.

Market demand for coal. When the price of natural gas and/or oil declines relative to that of coal, some users of coal may choose to burn natural gas or oil instead of coal. Market demand for coal may also decline as a result of an economic slowdown. Sustained low natural gas prices may also cause users of coal to phase out or close existing coal using operations. If users of coal burn less coal or eliminate the use of coal there would be less need for our product.

Environmental concerns regarding coal.Environmental concerns about greenhouse gases, toxic wastewater discharges and the potential hazardous nature of coal combustion waste could lead to regulations that discourage the burning of coal. Such regulations could mandate that electric power generating companies purchase a minimum amount of power from renewable energy sources such as wind,

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hydroelectric, solar and geothermal. This could result in utilities burning less coal, which would reduce the generation of tax credits.

 •The refined coal operation in which we have invested and the by-products from such operations may result in environmental and product liability claims and environmental compliance costs.The construction and operation of the refined coal operation are subject to Federal, state and local laws, regulations and potential liabilities arising under or relating to the protection or preservation of the environment, natural resources and human health and safety. Such laws and regulations generally require the operations and/or the utilities at which the operations are located to obtain and comply with various environmental registrations, licenses, permits, inspections and other approvals. Such laws and regulations also impose liability, without regard to fault or the legality of a party’s conduct, on certain entities that are considered to have contributed to, or are otherwise involved in, the release or threatened release of hazardous substances into the environment. Such hazardous substances could be released as a result of burning refined coal in a number of ways, including air emissions, waste water, and by-products such as fly ash. One party may, under certain circumstances, be required to bear more than its share or the entire share of investigation and cleanup costs at a site if payments or participation cannot be obtained from other responsible parties. We may be exposed to the risk of becoming liable for environmental damage we may have had little, if any, involvement in creating. Such risk remains even after production ceases at an operation to the extent the environmental damage can be traced to the types of chemicals or compounds used or operations conducted in connection with the use of refined coal.

No assurances can be given that contractual arrangements and precautions taken to ensure assumption of these risks by facility owners or operators will result in that facility owner or operator accepting full responsibility for any environmental damage. It is also not uncommon for private claims by third parties alleging contamination to also include claims for personal injury, property damage, diminution of property or similar claims. Furthermore, many environmental, health and safety laws authorize citizen suits, permitting third parties to make claims for violations of laws or permits and force compliance. Our insurance may not cover all environmental risk and costs or may not provide sufficient coverage in the event of an environmental claim. If significant uninsured losses arise from environmental damage or product liability claims, or if the costs of environmental compliance increase for any reason, our results of operations and financial condition could be adversely affected.

 •Operation of the refined coal operation.We rely on an unrelated third party to operate the refined coal operation. Should the third party fail to perform or underperform in the operation, management or regulatory compliance of the facility, our results of operations and financial condition could be adversely affected as we are not experienced in operating a refined coal facility.

 •Utilization of tax credits.If we do not generate sufficient taxable income to utilize the tax credits earned by our refined coal operation, we could incur write-offs of the related tax attributes which could adversely affect our results of operations and financial condition. In addition, this could adversely reduce our liquidity reserves as we expect to incur operating losses sustained by the refined coal operation.

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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. Our consolidated and unconsolidated ethanol subsidiaries have certain restrictions on their ability to pay dividends to us. During the first ninesix months of fiscal year 2016,2017, One Earth and NuGen paid dividends to REX of approximately $5.1 million and $5.8 million, respectively.million. During the first six months of fiscal year 2017, NuGen did not pay dividends.

 

Item 3.Defaults upon Senior Securities

NoneNot Applicable

 

Item 4.Mine Safety Disclosures

NoneNot Applicable

Item 5.Other Information

None

 

Item 6.Exhibits

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The following exhibits are filed with this report:

 

10(a) First Amendment to Employment Agreement dated June 2, 2015 between Rex Radio and Television, Inc. and Stuart A. Rose
10(b)First Amendment to Employment Agreement dated June 2, 2015 between Rex Radio and Television, Inc. and Zafar Rizvi
10(c)First Amendment to Employment Agreement dated June 2, 2015 between Rex Radio and Television, Inc. and Douglas L. Bruggeman
31Rule 13a-14(a)/15d-14(a) Certifications

32Section 1350 Certifications

101The following information from REX American Resources Corporation Quarterly Report on Form 10-Q for the quarter ended OctoberJuly 31, 2016, 2017, formatted in XBRL: (i) Consolidated Condensed Balance Sheets, (ii) Consolidated Condensed Statements of Operations, (iii) Consolidated Condensed Statements of Equity, (iv) Consolidated Condensed Statements of Cash Flows and (v) Notes to Consolidated Condensed Financial Statements.
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SIGNATURES

 

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.

 

REX American Resources Corporation

Registrant

REX American Resources Corporation
Registrant

 

Signature Title Date
     

/s/ Zafar Rizvi

(Zafar Rizvi)

 Chief Executive Officer and President
 (Zafar Rizvi)
(Chief Executive Officer)
 December 1, 2016September 6, 2017
     

/s/ Douglas L. Bruggeman

(Douglas L. Bruggeman)

 Vice President, Finance and Treasurer
(Douglas L. Bruggeman)
(Chief Financial Officer)
 December 1, 2016September 6, 2017
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