Edgar Filing: REX AMERICAN RESOURCES Corp

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D.C. 20549

FORM 10-Q


(Mark One)
x	QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

	For the quarterly period ended July 31, 2012

OR

o	TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

	For the transition period from _________ to _________

Commission File Number 001-09097

REX AMERICAN RESOURCES CORPORATION

(Exact name of registrant as specified in its charter)


	Delaware	31-1095548
	(State or other jurisdiction of	(I.R.S. Employer
	incorporation or organization)	Identification Number)


	2875 Needmore Road, Dayton, Ohio	45414
	(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.

Yes x 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).

Yes x 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 filer o	Accelerated filer x
Non-accelerated filer o (Do not check if a smaller reporting company)	Smaller reporting company o

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

At the close of business on September 4, 2012 the registrant had 8,238,886 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 Sheets	3
	Consolidated Condensed Statements of Operations	4
	Consolidated Condensed Statements of Equity	5
	Consolidated Condensed Statements of Cash Flows	6
	Notes to Consolidated Condensed Financial Statements	7

Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	25

Item 3.	Quantitative and Qualitative Disclosures About Market Risk	39

Item 4.	Controls and Procedures	41

PART II.	OTHER INFORMATION

Item 1.	Legal Proceedings	41

Item 1A.	Risk Factors	41

Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	41

Item 3.	Defaults upon Senior Securities	42

Item 4.	Mine Safety Disclosures	42

Item 5.	Other Information	42

Item 6.	Exhibits	42

PART I. FINANCIAL INFORMATION

Item 1. Financial Statements

REX AMERICAN RESOURCES CORPORATION AND SUBSIDIARIES
Consolidated Condensed Balance Sheets
Unaudited


	July 31, 2012			January 31, 2012

	(In Thousands)
Assets
Current assets:
Cash and cash equivalents	$	63,962		$	75,013
Accounts receivable		14,879			12,784
Inventories		29,354			30,349
Refundable income taxes		1,513			1,816
Prepaid expenses and other		4,576			3,987
Deferred taxes, net		2,530			3,090

Total current assets		116,814			127,039
Property and equipment, net		232,245			240,084
Other assets		7,215			7,884
Equity method investments		59,564			61,679
Restricted investments and deposits		683			1,363

Total assets	$	416,521		$	438,049

Liabilities and equity:
Current liabilities:
Current portion of long-term debt, alternative energy	$	12,454		$	14,972
Current portion of long-term debt, other		261			250
Accounts payable, trade		3,204			6,985
Deferred income		1,315			1,864
Accrued real estate taxes		2,100			2,750
Accrued payroll and related items		660			2,882
Derivative financial instruments		1,766			1,694
Other current liabilities		4,658			5,844

Total current liabilities		26,418			37,241

Long-term liabilities:
Long-term debt, alternative energy		99,362			107,706
Long-term debt, other		687			821
Deferred taxes		4,642			4,642
Deferred income		143			552
Derivative financial instruments		1,766			2,541
Other long-term liabilities		2,731			2,703

Total long-term liabilities		109,331			118,965

Equity:
REX shareholders’ equity:
Common stock		299			299
Paid-in capital		143,667			142,994
Retained earnings		326,062			324,323
Treasury stock		(217,647	)		(215,105	)

Total REX shareholders’ equity		252,381			252,511
Noncontrolling interests		28,391			29,332

Total equity		280,772			281,843

Total liabilities and equity	$	416,521		$	438,049

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

REX AMERICAN RESOURCES CORPORATION AND SUBSIDIARIES
Consolidated Condensed Statements Of Operations
Unaudited


	Three Months Ended July 31,						Six Months Ended July 31,

	2012			2011			2012			2011


	(In Thousands, Except Per Share Amounts)

Net sales and revenue	$	153,164		$	73,796		$	304,178		$	154,959
Cost of sales		146,370			74,015			291,918			150,448

Gross profit (loss)		6,794			(219	)		12,260			4,511
Selling, general and administrative expenses		(3,584	)		(1,974	)		(6,171	)		(4,285	)
Equity in (loss) income of unconsolidated affiliates		(481	)		3,761			(39	)		9,543
Income from synthetic fuel investments		—			2,883			—			2,883
Interest income		41			101			90			271
Interest expense		(1,173	)		(638	)		(2,527	)		(1,301	)
Losses on derivative financial instruments, net		(79	)		(757	)		(226	)		(689	)

Income from continuing operations before income taxes		1,518			3,157			3,387			10,933
Provision for income taxes		(460	)		(1,499	)		(1,003	)		(4,232	)

Income from continuing operations		1,058			1,658			2,384			6,701
Income from discontinued operations, net of tax		175			335			348			714
Gain on disposal of discontinued operations, net of tax		56			40			49			174

Net income		1,289			2,033			2,781			7,589
Net (income) loss attributable to noncontrolling interests		(483	)		314			(1,042	)		(590	)

Net income attributable to REX common shareholders	$	806		$	2,347		$	1,739		$	6,999


Weighted average shares outstanding – basic		8,347			9,513			8,354			9,473


Basic income per share from continuing operations attributable to REX common shareholders	$	0.07		$	0.21		$	0.16		$	0.64
Basic income per share from discontinued operations attributable to REX common shareholders		0.02			0.03			0.04			0.08
Basic income per share on disposal of discontinued operations attributable to REX common shareholders		0.01			0.01			0.01			0.02

Basic net income per share attributable to REX common shareholders	$	0.10		$	0.25		$	0.21		$	0.74


Weighted average shares outstanding – diluted		8,385			9,550			8,414			9,557


Diluted income per share from continuing operations attributable to REX common shareholders	$	0.07		$	0.21		$	0.16		$	0.64
Diluted income per share from discontinued operations attributable to REX common shareholders		0.02			0.03			0.04			0.07
Diluted income per share on disposal of discontinued operations attributable to REX common shareholders		0.01			0.01			0.01			0.02

Diluted net income per share attributable to REX common shareholders	$	0.10		$	0.25		$	0.21		$	0.73


Amounts attributable to REX common shareholders:
Income from continuing operations, net of tax	$	575		$	1,972		$	1,342		$	6,111
Income from discontinued operations, net of tax		231			375			397			888

Net income	$	806		$	2,347		$	1,739		$	6,999

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

REX AMERICAN RESOURCES CORPORATION AND SUBSIDIARIES
Consolidated Condensed Statements Of Equity
Unaudited
(In Thousands)


	REX Shareholders


	Common Shares Issued				Treasury						Paid-in Capital		Retained Earnings		Noncontrolling Interests			Total Equity

	Shares		Amount		Shares			Amount


Balance at January 31, 2012		29,853	$	299		21,523		$	(215,105	)	$	142,994	$	324,323	$	29,332		$	281,843

Net income														1,739		1,042			2,781

Treasury stock acquired						170			(3,541	)									(3,541	)

Noncontrolling interests distribution and other																(1,983	)		(1,983	)

Stock options and related tax effects		—		—		(99	)		999			673		—		—			1,672


Balance at July 31, 2012		29,853	$	299		21,594		$	(217,647	)	$	143,667	$	326,062	$	28,391		$	280,772


	Common Shares Issued				Treasury						Paid-in Capital		Retained Earnings		Noncontrolling Interests			Total Equity

	Shares		Amount		Shares			Amount


Balance at January 31, 2011		29,853	$	299		20,461		$	(193,713	)	$	142,293	$	296,053	$	25,032		$	269,964

Net income														6,999		590			7,589

Noncontrolling interests distribution																(1,796	)		(1,796	)

Other																(192	)		(192	)

Treasury stock acquired						393			(6,353	)									(6,353	)

Stock options and related tax effects		—		—		(436	)		4,066			86		—		—			4,152


Balance at July 31, 2011		29,853	$	299		20,418		$	(196,000	)	$	142,379	$	303,052	$	23,634		$	273,364

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

REX AMERICAN RESOURCES CORPORATION AND SUBSIDIARIES
Consolidated Condensed Statements Of Cash Flows
Unaudited


	Six Months Ended July 31,

	2012			2011

	(In Thousands)
Cash flows from operating activities:
Net income including noncontrolling interests	$	2,781		$	7,589
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization		8,241			5,519
Impairment charges and other		143			1,153
Loss (income) from equity method investments		39			(9,543	)
Income from synthetic fuel investments		—			(2,883	)
Gain on disposal of real estate and property and equipment		(83	)		(271	)
Dividends received from equity method investees		2,005			2,316
Deferred income		(958	)		(2,367	)
Derivative financial instruments		(703	)		(608	)
Deferred income tax		553			2,859
Changes in assets and liabilities:
Accounts receivable		(2,095	)		1,738
Inventories		995			(2,551	)
Other assets		367			9,890
Accounts payable, trade		(3,781	)		(1,652	)
Other liabilities		(4,030	)		1,665

Net cash provided by operating activities		3,474			12,854

Cash flows from investing activities:
Capital expenditures		(2,320	)		(637	)
Proceeds from sale of synthetic fuel investment		—			2,883
Restricted investments		680			—
Proceeds from sale of real estate and property and equipment		2,195			1,603

Net cash provided by investing activities		555			3,849

Cash flows from financing activities:
Payments of long-term debt		(10,985	)		(5,136	)
Repayments of contingent consideration		—			(1,313	)
Stock options exercised		358			312
Noncontrolling interests distribution and other		(1,983	)		(1,988	)
Treasury stock acquired		(2,470	)		(3,162	)

Net cash used in financing activities		(15,080	)		(11,287	)

Net (decrease) increase in cash and cash equivalents		(11,051	)		5,416
Cash and cash equivalents, beginning of period		75,013			91,019

Cash and cash equivalents, end of period	$	63,962		$	96,435


Non cash financing activities - Cashless exercise of stock options	$	1,071		$	—

Non cash investing activities - Accrued capital expenditures	$	—		$	440

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

REX AMERICAN RESOURCES CORPORATION AND SUBSIDIARIES

NOTES TO UNAUDITED CONSOLIDATED CONDENSED FINANCIAL STATEMENTS
July 31, 2012

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, 2012 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, 2012 (fiscal year 2011). 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, 2012. 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. The Company includes the results of operations of One Earth Energy, LLC (“One Earth”) in its Consolidated Condensed Statements of Operations on a delayed basis of one month. Effective November 1, 2011, the Company acquired a majority ownership interest in NuGen Energy, LLC (“NuGen”), and have included the results of operations in its Consolidated Condensed Statements of Operations on a prospective basis.

Nature of Operations – The Company operates in two reportable segments, alternative energy and real estate. The Company substantially completed the exit of its retail business during the second quarter of fiscal year 2009, although it continues to recognize revenue and expense associated with administering extended service policies as discontinued operations.

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 2011 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.

Revenue Recognition

The Company recognizes sales from the production of ethanol, distillers grains and non-food grade corn oil when title transfers to customers, upon shipment from its plant. Shipping and handling charges to customers are included in net sales and revenue.

The Company includes income from real estate leasing activities in net sales and revenue. The Company accounts for these leases as operating leases. Accordingly, minimum rental revenue is recognized on a straight-line basis over the term of the lease.

The Company sold, prior to its exit of the retail business, extended service policies covering periods beyond the normal manufacturers’ warranty periods, usually with terms of coverage (including manufacturers’ warranty periods) of between 12 to 60 months. Contract revenues and sales commissions are deferred and amortized on a straight-line basis over the life of the contracts after the expiration of applicable manufacturers’ warranty periods. The Company retains the obligation to perform warranty service and such costs are charged to operations as incurred. All related revenue and expense is classified as discontinued operations.

Cost of Sales

Alternative energy cost of sales includes depreciation, costs of raw materials, inbound freight charges, purchasing and receiving costs, inspection costs, shipping costs, other distribution expenses, warehousing costs, plant management, certain compensation costs, and general facility overhead charges.

Real estate cost of sales includes depreciation, real estate taxes, insurance, repairs and maintenance and other costs directly associated with operating the Company’s portfolio of real property.

Selling, General and Administrative Expenses

The Company includes non-production related costs from its alternative energy segment such as professional fees, selling charges and certain payroll in selling, general and administrative expenses.

The Company includes costs not directly related to operating its portfolio of real property from its real estate segment such as certain payroll and related costs, professional fees and other general expenses in selling, general and administrative expenses.

The Company includes costs associated with its corporate headquarters such as certain payroll and related costs, professional fees and other general expenses in selling, general and administrative expenses.

Interest Cost

No interest was capitalized for the six months ended July 31, 2012 and 2011. Cash paid for interest for the three months ended July 31, 2012 and 2011 was approximately $1,152,000 and $658,000, respectively. Cash paid for interest for the six months ended July 31, 2012 and 2011 was approximately $2,735,000 and $1,353,000, respectively.

Financial Instruments

The Company uses derivative financial instruments to manage its balance of fixed and variable rate debt. The Company does not hold or issue derivative financial instruments for trading or speculative purposes. Interest rate swap agreements involve the exchange of fixed and variable rate interest payments and do not represent an actual exchange of the notional amounts between the parties. The swap agreements were not designated for hedge accounting pursuant to ASC 815, Derivatives and Hedging (“ASC 815”). The interest rate swaps are recorded at their fair values and the changes in fair values are recorded as gain or loss on derivative financial instruments in the Consolidated Condensed Statements of Operations. The Company paid settlements of interest rate swaps of approximately $929,000 and $1,297,000 for the six months ended July 31, 2012 and 2011, respectively.

Forward grain purchase and ethanol and distillers grains sale contracts are accounted for under the “normal purchases and normal sales” scope exemption of ASC 815 because these arrangements are for purchases of grain that will be delivered in quantities expected to be used by the Company and sales of ethanol and distillers grains quantities expected to be produced by the Company over a reasonable period of time in the normal course of business.

Income Taxes

The Company applies an effective tax rate to interim periods that is consistent with the Company’s estimated annual tax rate. The Company provides for deferred tax liabilities and assets for the future tax consequences attributable to differences between the financial statement carrying amounts of existing assets and liabilities and their respective tax basis and operating loss and tax credit carryforwards. The Company provides for a valuation allowance if, based on the weight of available evidence, it is more likely than not that some or all of the deferred tax assets will not be realized. The Company paid income taxes of approximately $51,000 during the six months ended July 31, 2012. The Company paid no income taxes during the six months ended July 31, 2011. During the six months ended July 31, 2011, the Company received tax refunds of $7,247,000. The Company received no refunds during the six months ended July 31, 2012.

As of July 31, 2012, total unrecognized tax benefits were approximately $2,157,000 and accrued penalties and interest were $358,000. If the Company were to prevail on all unrecognized tax benefits recorded, approximately $82,000 of the reserve would benefit the effective tax rate. In addition, the impact of penalties and interest would also benefit the effective tax rate. Interest and penalties associated with unrecognized tax benefits are recorded within income tax expense. On a quarterly and annual basis, the Company accrues for the effects of open uncertain tax positions and the related potential penalties and interest.

Inventories

Inventories are carried at the lower of cost or market on a first-in, first-out basis. Alternative energy segment inventory includes direct production costs and certain overhead costs such as depreciation, property taxes and utilities related to producing ethanol and related by-products. Inventory is permanently written down for instances when cost exceeds estimated net realizable value; such write-downs are based primarily upon commodity prices as the market value of inventory is often dependent upon changes in commodity prices. The write-down of inventory was approximately $122,000 and $153,000 at July 31, 2012 and January 31, 2012, respectively. 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 at July 31, 2012 and January 31, 2012 are as follows (amounts in thousands):


	July 31, 2012		January 31, 2012


Ethanol and other finished goods	$	5,447	$	5,318
Work in process, net		4,454		3,819
Grain and other raw materials		19,453		21,212

Total	$	29,354	$	30,349

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 3 to 20 years for fixtures and equipment.

In accordance with ASC 360-05 “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. Impairment charges were approximately $0.1 million and $1.2 million in the first six months of fiscal years 2012 and 2011, respectively. These charges relate to the Company’s real estate segment. Impairment charges result from the Company’s management performing cash flow analysis and represent management’s estimate of the excess of net book value over fair value. Fair value is estimated using expected future cash flows on a discounted basis or appraisals of specific properties as appropriate. Long-lived assets are tested for recoverability whenever events or changes in circumstances indicate that its carrying amount may not be recoverable. Generally, declining cash flows from an ethanol plant or deterioration in local real estate market conditions are indicators of possible impairment.

Investments and Deposits

Restricted investments, which are principally money market mutual funds and cash deposits, are stated at cost plus accrued interest, which approximates market. Restricted investments at July 31, 2012 and January 31, 2012 are required by two states to cover possible future claims under extended service policies over the remaining lives of the service policy contracts. In accordance with ASC 320, “Investments-Debt and Equity Securities” the Company has classified these investments as held-to-maturity. The investments had maturity dates of less than one year at July 31, 2012 and January 31, 2012. The Company has the intent and ability to hold these securities to maturity.

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. The results of One Earth are included on a delayed basis of one month. The Company accounts for investments in limited liability companies in which it may have a less than 20% ownership interest, using the equity method of accounting when the factors discussed in ASC 323 “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. Investments in which the Company does not have the ability to exercise significant influence over operating and financial matters are accounted for using the cost method. The Company accounts for its investments in Big River Resources, LLC (“Big River”) and Patriot Holdings, LLC (“Patriot”) using the equity method of accounting and includes the results of these entities on a delayed basis of one month.

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

Accounting Changes and Recently Issued Accounting Standards

Effective February 1, 2012, the Company was required to adopt the third phase of amended guidance in ASC 820 “Fair Value Measurements and Disclosures”. The amendment established common fair value measurement and disclosure requirements by improving comparability of fair value measurements presented and disclosed in financial statements prepared in accordance with generally accepted accounting principles in the United States of America (“GAAP”) and those prepared in conformity with International Financial Reporting Standards. The amended guidance clarified the application of existing requirements and requires

additional disclosure for Level 3 measurements regarding the sensitivity of fair value to changes in unobservable inputs and any interrelationships between those inputs. The adoption of this amended guidance did expand disclosure related to fair value but, otherwise, did not impact the Company’s financial statements.

Effective February 1, 2012, the Company was required to adopt the amended guidance in ASC 220 “Comprehensive Income”. This amendment increased the prominence of other comprehensive income in the financial statement by eliminating the option to present other comprehensive income in the statement of stockholders’ equity, and rather requiring comprehensive income to be reported in either a single continuous statement or in two separate but consecutive statements reporting net income and other comprehensive income. The adoption of this amended guidance did not impact the Company’s financial statements.

Note 3. Leases

At July 31, 2012, the Company has lease agreements, as landlord, for all or portions of six owned former retail stores and one owned former distribution center. The Company also has seasonal (temporary) lease agreements, as landlord for four owned properties. 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 2013	$	693
2014		1,261
2015		1,070
2016		511
2017		443
Thereafter		1,453

Total	$	5,431

Note 4. Fair Value

The Company applies ASC 820, Fair Value Measurements and Disclosures, (“ASC 820”) which provides a framework for measuring fair value under GAAP. 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. ASC 820 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 cash equivalents, investment in cooperative, restricted investments and derivative liabilities at fair value.

Level 1 – Quoted prices in active markets for identical assets or liabilities. Level 1 assets and liabilities include debt and equity securities and derivative contracts that are traded in an active exchange market, as well as certain U.S. Treasury securities that are highly liquid and are actively traded in over-the-counter markets.

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

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

The fair values of interest rate swaps are determined by using quantitative models that discount future cash flows using the LIBOR forward interest rate curve. 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, as applicable, are determined by using various models that discount future expected cash flows. Estimation risk is greater for vacant properties as the probability of expected cash flows from the use of vacant properties is difficult to predict.

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

Financial assets and liabilities measured at fair value on a recurring basis at July 31, 2012 are summarized below (amounts in thousands):


	Level 1		Level 2		Level 3		Fair Value


Cash equivalents	$	2	$	—	$	—	$	2
Money market mutual fund (1)		320		—		—		320
Investment in cooperative (1)		—		—		219		219

Total assets	$	322	$	—	$	219	$	541

Interest rate swap derivative liabilities	$	—	$	3,532	$	—	$	3,532

Financial assets and liabilities measured at fair value on a recurring basis at January 31, 2012 are summarized below (amounts in thousands):


	Level 1		Level 2		Level 3		Fair Value


Cash equivalents	$	2	$	—	$	—	$	2
Money market mutual fund (1)		620		—		—		620
Investment in cooperative (1)		—		—		219		219

Total assets	$	622	$	—	$	219	$	841

Interest rate swap derivative liabilities	$	—	$	4,235	$	—	$	4,235

(1) The money market mutual fund is included in “Restricted investments and deposits” and the investment in cooperative is included in “Other assets” on the accompanying Consolidated Condensed Balance Sheets.

The following table provides a reconciliation of the activity related to assets (investment in cooperative) measured at fair value on a recurring basis using Level 3 inputs (amounts in thousands):


Balance, January 31, 2012	$	219
Current period activity		—

Balance, July 31, 2012	$	219

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.

Assets measured at fair value on a non-recurring basis subsequent to January 31, 2012 are summarized below (amounts in thousands):


	Level 1		Level 2		Level 3		Total Losses


Property and equipment, net	$	—	$	—	$	600	$	143

Assets measured at fair value on a non-recurring basis over various dates through January 31, 2012 are summarized below (amounts in thousands):


	Level 1		Level 2		Level 3		Total Losses


Property and equipment, net	$	—	$	—	$	8,803	$	1,227

The fair value of the Company’s debt is approximately $112.8 million and $123.7 million at July 31, 2012 and January 31, 2012, respectively. The fair value was estimated with Level 2 inputs using a discounted cash flow analysis and the Company’s estimate of market rates of interest for similar loan agreements with companies that have a similar credit risk.

Note 5. Property and Equipment

The components of property and equipment at July 31, 2012 and January 31, 2012 are as follows (amounts in thousands):


	July 31, 2012			January 31, 2012


Land and improvements	$	24,455		$	25,094
Buildings and improvements		39,461			40,710
Machinery, equipment and fixtures		221,348			212,797
Leasehold improvements		—			366
Construction in progress		43			7,194

		285,307			286,161
Less: accumulated depreciation		(53,062	)		(46,077	)


	$	232,245		$	240,084

Note 6. Other Assets

The components of other assets at July 31, 2012 and January 31, 2012 are as follows (amounts in thousands):


	July 31, 2012		January 31, 2012


Deferred financing costs, net	$	1,038	$	1,306
Prepaid commissions		393		729
Deposits		2,514		2,564
Real estate taxes refundable		1,969		1,969
Other		1,301		1,316

Total	$	7,215	$	7,884

Note 7. Long Term Debt and Interest Rate Swaps

One Earth Energy Subsidiary Level Debt

In September 2007, One Earth entered into a $111,000,000 financing agreement consisting of a construction loan agreement for $100,000,000 together with a $10,000,000 revolving loan and a $1,000,000 letter of credit with First National Bank of Omaha (“the Bank”). The construction loan was converted into a term loan on July 31, 2009 as all of the requirements, for such conversion, of the construction and term loan agreement were fulfilled. The term loan bears interest at variable interest rates ranging from LIBOR plus 280 basis points to LIBOR plus 300 basis points (3.4% -3.5% at July 31, 2012). Beginning with the first quarterly payment on October 8, 2009, payments are due in 19 quarterly payments of principal plus accrued interest with the principal portion calculated based on a 120 month amortization schedule. One final installment will be required on the maturity date (July 31, 2014) for the remaining unpaid principal balance with accrued interest. Principal payments equal to 20% of annual excess cash flows are also due. Such payments cannot exceed $6 million in a year.

Borrowings are secured by all of the assets of One Earth. This debt is recourse only to One Earth and not to REX American Resources Corporation or any of its other subsidiaries. As of July 31, 2012, approximately $60.9 million was outstanding on the term loan. One Earth is also subject to certain financial covenants under the loan agreement, including required levels of EBITDA, debt service coverage ratio requirements and working capital requirements. One Earth was in compliance with these covenants, as applicable, at July 31, 2012. One Earth has paid approximately $1.4 million in financing costs. These costs are recorded as deferred financing costs and are amortized ratably over the term of the loan.

The Company’s proportionate share of restricted net assets related to One Earth was approximately $77.5 million and $70.2 million at July 31, 2012 and January 31, 2012, respectively. Restricted net assets may not be paid in the form of dividends or advances to the parent company or other members of One Earth per the terms of the loan agreement with the Bank.

As of July 31, 2012, One Earth has no outstanding borrowings on the $10,000,000 revolving loan, which expires May 29, 2013, nor any outstanding letters of credit.

One Earth entered into two forward interest rate swaps in the notional amounts of $50.0 million and $25.0 million with the Bank. The swap settlements commenced as of July 31, 2009; the $50.0 million swap terminates on July 8, 2014 and the $25.0 million swap terminated on July 31, 2011. The $50.0 million swap fixed a portion of the variable interest rate of the term loan subsequent to the plant completion date at 7.9% while the $25.0 million swap fixed the rate at 5.49%. At July 31, 2012 and January 31, 2012, the Company recorded a liability of approximately $3.5 million and $4.2 million, respectively, related to the fair value of the swap. The change in fair value is recorded in the Consolidated Condensed Statements of Operations.

NuGen Energy Subsidiary Level Debt

In November 2011, NuGen entered into a $65,000,000 financing agreement consisting of a term loan agreement for $55,000,000 and a $10,000,000 revolving loan with First National Bank of Omaha (“the Bank”). The term loan bears interest at variable interest rate of LIBOR plus 325 basis points, subject to a 4% floor (4% at July 31, 2012). Beginning with the first quarterly payment on February 1, 2012, payments are due in 19 quarterly payments of principal plus accrued interest with the principal portion calculated based on a 120 month amortization schedule. One final installment will be required on the maturity date (October 31, 2016) for the remaining unpaid principal balance with accrued interest. Principal payments equal to 40% of annual excess cash flows are also due. Such payments cannot exceed $5 million in a year.

Borrowings are secured by all of the assets of NuGen. This debt is recourse only to NuGen and not to REX American Resources Corporation or any of its other subsidiaries. As of July 31, 2012, approximately $50.9 million was outstanding on the term loan. NuGen is also subject to certain financial covenants under the loan agreement, including required levels of EBITDA, debt service coverage ratio requirements and working capital requirements. NuGen was in compliance with these covenants, as applicable, at July 31, 2012. NuGen has paid approximately $0.6 million in financing costs. These costs are recorded as deferred financing costs and are amortized ratably over the term of the loan.

The Company’s proportionate share of restricted net assets related to NuGen was approximately $54.4 million and approximately $50.4 million at July 31, 2012 and January 31, 2012, respectively. Restricted net assets may not be paid in the form of dividends or advances to the parent company or other members of NuGen per the terms of the loan agreement with the Bank.

NuGen has no outstanding borrowings on the $10,000,000 revolving loan as of July 31, 2012.

Note 8. Financial Instruments

The Company uses interest rate swaps to manage its interest rate exposure at One Earth by fixing the interest rate on a portion of the entity’s variable rate debt. The Company does not

engage in trading activities involving derivative contracts for which a lack of marketplace quotations would necessitate the use of fair value estimation techniques. The notional amounts and fair values of derivatives, all of which are not designated as cash flow hedges at July 31, 2012 are summarized in the table below (amounts in thousands):


	Notional Amount		Fair Value Liability


Interest rate swap	$	39,859	$	3,532

As the interest rate swaps are not designated as cash flow hedges, the unrealized gain and loss on the derivatives is reported in current earnings. The Company reported losses of $79,000 and $757,000 in the second quarter of fiscal years 2012 and 2011, respectively. The Company reported losses of $226,000 and $689,000 in the first six months of fiscal years 2012 and 2011, respectively.

Note 9. Stock Option Plans

The Company has stock-based compensation plans under which stock options have been granted to directors, officers and key employees at the market price on the date of the grant. No options have been granted since fiscal year 2004.

The total intrinsic value of options exercised during the six months ended July 31, 2012 and 2011 was approximately $1.8 million and $3.1 million, respectively, resulting in tax deductions to realize benefits of approximately $0.3 million and $0.6 million, respectively. The following table summarizes options granted, exercised and canceled or expired during the six months ended July 31, 2012:


	Shares			Weighted Average Exercise Price		Weighted Average Remaining Contractual Term (in years)		Aggregate Intrinsic Value (in thousands)

Outstanding at January 31, 2012		268,723		$	13.15
Exercised		(99,968	)	$	14.30

Outstanding and exercisable at July 31, 2012		168,755		$	12.46		1.5	$	875

During the first six months of fiscal year 2012, certain officers and directors of the Company tendered 32,935 shares of the Company’s common stock as payment of the exercise price of stock options exercised pursuant to the Company’s Stock-for-Stock and Cashless Option Exercise Rules and Procedures, adopted on June 4, 2001. The purchase price was $32.53 per share.

At July 31, 2012, there was no unrecognized compensation cost related to nonvested stock options.

Note 10. Income Per Share from Continuing Operations Attributable to REX Common Shareholders

The following table reconciles the computation of basic and diluted net income per share from continuing operations for the periods presented (in thousands, except per share amounts):


	Three Months Ended July 31, 2012						Three Months Ended July 31, 2011

	Income		Shares		Per Share		Income		Shares		Per Share

Basic income per share from continuing operations attributable to REX common shareholders	$	575		8,347	$	0.07	$	1,972		9,513	$	0.21

Effect of stock options		—		38				—		37

Diluted income per share from continuing operations attributable to REX common shareholders	$	575		8,385	$	0.07	$	1,972		9,550	$	0.21


	Six Months Ended July 31, 2012						Six Months Ended July 31, 2011

	Income		Shares		Per Share		Income		Shares		Per Share

Basic income per share from continuing operations attributable to REX common shareholders	$	1,342		8,354	$	0.16	$	6,111		9,473	$	0.64

Effect of stock options		—		60				—		84

Diluted income per share from continuing operations attributable to REX common shareholders	$	1,342		8,414	$	0.16	$	6,111		9,557	$	0.64

For the six months ended July 31, 2011, a total of 12,468 shares subject to outstanding options were not included in the common equivalent shares outstanding calculation as the effect from these shares was antidilutive. There were no such shares for the three and six months ended July 31, 2012 and for the three months ended July 31, 2011.

Note 11. Investments and Restricted Deposits

The Company has approximately $383,000 and $743,000 at July 31, 2012 and January 31, 2012, respectively, on deposit with the Florida Department of Financial Services to secure its obligation to fulfill future obligations related to extended warranty contracts sold in the state of Florida. As such, this deposit is restricted from use for general corporate purposes.

In addition to the deposit with the Florida Department of Financial Services, the Company has $300,000 at July 31, 2012 and $620,000 at January 31, 2012 invested in a money market mutual fund to satisfy Florida Department of Financial Services regulations. As such, this investment is restricted from use for general corporate purposes.

The following table summarizes equity method investments at July 31, 2012 and January 31, 2012 (amounts in thousands):


Entity	Ownership Percentage			Carrying Amount July 31, 2012		Carrying Amount January 31, 2012


Big River		10	%	$	33,026	$	34,370
Patriot		27	%		26,538		27,309

Total Equity Method Investments				$	59,564	$	61,679

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


	Three Months Ended July 31,					Six Months Ended July 31,
	2012			2011		2012			2011


Big River	$	104		$	1,583	$	661		$	2,854
Patriot		(585	)		469		(700	)		1,373
NuGen		—			1,709		—			5,316

Total	$	(481	)	$	3,761	$	(39	)	$	9,543

Effective July 1, 2010, the Company purchased a 48% equity interest in NuGen which operates an ethanol producing facility in Marion, South Dakota with an annual nameplate capacity of 100 million gallons. The Company accounted for this investment using the equity method of accounting. On November 1, 2011, the Company acquired an additional 50% equity interest in NuGen. Following the purchase, the Company owned all of the outstanding Class A membership interest units in NuGen, representing a 100% voting interest and a 98% equity interest in NuGen. Effective November 1, 2011, the Company ceased using the equity method of accounting and began consolidating the results of NuGen. Prior to consolidation, the Company recorded the results of NuGen on a one month lag. During fiscal year 2011, NuGen adopted the same fiscal year as the Company. As a result, the Company no longer records the results of NuGen on a one month lag. NuGen repurchased shares from noncontrolling interests holders during fiscal year 2012. This increased the Company’s equity interest in NuGen to 99%.

Undistributed earnings of equity method investees totaled approximately $20.7 million and $22.8 million at July 31, 2012 and January 31, 2012, respectively. During the first six months of fiscal years 2012 and 2011, the Company received dividends from equity method investees of approximately $2.0 million and $2.3 million, respectively.

Summarized financial information for each of the Company’s equity method investees except for NuGen is presented in the following table for the three and six months ended June 30,

2012 and June 30, 2011. The summarized financial information for NuGen is presented for the three and six months ended July 31, 2011 (amounts in thousands):


Three Months Ended June 30, 2012	Big River		Patriot


Net sales and revenue	$	258,848	$	81,578
Gross profit (loss)	$	8,507	$	(569	)
Income (loss) from continuing operations	$	1,068	$	(2,209	)
Net income (loss)	$	1,068	$	(2,209	)

Three Months Ended June 30, 2011 and July 31, 2011	Big River		Patriot			NuGen


Net sales and revenue	$	236,478	$	101,650		$	86,913
Gross profit	$	8,402	$	4,071		$	6,103
Income from continuing operations	$	16,305	$	2,012		$	3,893
Net income	$	16,305	$	2,012		$	3,893

Six Months Ended June 30, 2012	Big River		Patriot


Net sales and revenue	$	549,851	$	171,389
Gross profit	$	22,515	$	1,208
Income (loss) from continuing operations	$	6,786	$	(2,645	)
Net income (loss)	$	6,786	$	(2,645	)

Six Months Ended June 30, 2011 and July 31, 2011	Big River		Patriot			NuGen


Net sales and revenue	$	478,706	$	189,966		$	168,051
Gross profit	$	31,473	$	9,534		$	14,992
Income from continuing operations	$	29,334	$	5,888		$	11,743
Net income	$	29,334	$	5,888		$	11,743

Patriot and Big River have debt agreements that limit and restrict amounts the companies can pay in the form of dividends or advances to owners. The restricted net assets of Patriot and Big River combined at July 31, 2012 and January 31, 2012 are approximately $408.1 million and $326.2 million, respectively. The Company’s proportionate share of restricted net assets of

Patriot and Big River combined at July 31, 2012 and January 31, 2012 are approximately $55.8 million and $44.2 million, respectively.

On April 27, 2011, Levelland Hockley voluntarily filed for protection under Chapter 11 of the United States Bankruptcy Code in the United States Bankruptcy Court, Northern District of Texas. In connection with the bankruptcy proceedings, the plant was sold on May 14, 2012 and on August 1, 2012, the bankruptcy case was converted to a Chapter 7 proceeding. As a result, we have no remaining ownership or financial interest in Levelland Hockley and have classified the results of Levelland Hockley as discontinued operations. No periods presented in the Consolidated Condensed Financial Statements were affected by this classification. However, future periodic reports filed with the Securities and Exchange Commission will be affected as years prior to fiscal year 2011 are required to be included in such filings.

Note 12. Income Taxes

The effective tax rate on consolidated pre-tax income from continuing operations was 30.3% for the three months ended July 31, 2012, and 47.5% for the three months ended July 31, 2011. The effective tax rate on consolidated pre-tax income from continuing operations was 29.6% for the six months ended July 31, 2012, and 38.7% for the six months ended July 31, 2011. The fluctuations in the effective tax rate primarily relate to the presentation of noncontrolling interests in the income of consolidated subsidiaries as noncontrolling interests are presented in the Consolidated Condensed Statements of Operations after the income tax provision or benefit.

The Company files a U.S. federal income tax return and income tax returns in various states. In general, the Company is no longer subject to U.S. federal, state or local income tax examinations by tax authorities for years ended January 31, 2008 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, 2012	$	2,484
Changes for prior years’ tax positions		31
Changes for current year tax positions		—

Unrecognized tax benefits, July 31, 2012	$	2,515

Note 13. Discontinued Operations

During fiscal year 2009, the Company completed the exit of its retail business. Accordingly, all operations of the Company’s former retail segment and certain sold properties have been classified as discontinued operations for all periods presented. Once real estate property has been sold, and no continuing involvement is expected, the Company classifies the results of the operations as discontinued operations. The results of operations were previously reported in the Company’s retail or real estate segment, depending on when the store ceased operations. Below is a table reflecting certain items of the Consolidated Condensed Statements

of Operations that were reclassified as discontinued operations for the periods indicated (amounts in thousands):


	Three Months Ended July 31,						Six Months Ended July 31,
	2012			2011			2012			2011

	(In Thousands)
Net sales and revenue	$	518		$	1,149		$	1,108		$	2,490
Cost of sales		42			266			154			541

Income before income taxes		310			525			598			1,108
Provision for income taxes		(135	)		(190	)		(250	)		(394	)

Income from discontinued operations, net of tax	$	175		$	335		$	348		$	714

Gain on disposal	$	99		$	62		$	83		$	266
Provision for income taxes		(43	)		(22	)		(34	)		(92	)

Gain on disposal of discontinued operations, net of tax	$	56		$	40		$	49		$	174

Note 14. 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 effect on the Company’s consolidated condensed financial statements.

One Earth and NuGen have combined forward purchase contracts for approximately 7.3 million bushels of corn, the principal raw material for their ethanol plants. They expect to take delivery of the grain through September 2012.

One Earth and NuGen have combined sales commitments for approximately 59.8 million gallons of ethanol, approximately 53,000 tons of distillers grains and approximately 1.3 million pounds of non-food grade corn oil. They expect to deliver the ethanol, distillers grains and non-food grade corn oil through December 2012.

Note 15. Segment Reporting

The Company has two segments: alternative energy and real estate. The Company evaluates the performance of each reportable segment based on segment profit. Segment profit excludes income taxes, indirect interest expense, discontinued operations, indirect interest income and certain other items that are included in net income determined in accordance with GAAP.

Segment profit includes realized and unrealized gains on derivative financial instruments. The following table summarizes segment and other results and assets (amounts in thousands):


	Three Months Ended July 31,						Six Months Ended July 31,
	2012			2011			2012			2011

Net sales and revenue:
Alternative energy	$	152,778		$	73,531		$	303,442		$	154,413
Real estate		386			265			736			546

Total net sales and revenues	$	153,164		$	73,796		$	304,178		$	154,959


Segment gross profit (loss):
Alternative energy	$	7,027		$	952		$	12,537		$	5,730
Real estate		(233	)		(1,171	)		(277	)		(1,219	)

Total gross profit (loss)	$	6,794		$	(219	)	$	12,260		$	4,511


	Three Months Ended July 31,						Six Months Ended July 31,
	2012			2011			2012			2011


Segment profit (loss):
Alternative energy	$	2,432		$	2,061		$	4,901		$	10,459
Real estate		(289	)		(1,218	)		(382	)		(1,331	)
Corporate expense		(623	)		(615	)		(1,136	)		(1,232	)
Interest expense		(21	)		(27	)		(45	)		(61	)
Income from synthetic fuel partnerships		—			2,883			—			2,883
Interest income		19			73			49			215

Income from continuing operations before income taxes and noncontrolling interests	$	1,518		$	3,157		$	3,387		$	10,933


	July 31, 2012			January 31, 2012

Assets:
Alternative energy	$	347,600		$	367,029
Real estate		14,911			17,458
Corporate		54,010			53,562

Total assets	$	416,521		$	438,049


	Three Months Ended July 31,						Six Months Ended July 31,
	2012			2011			2012			2011

Sales of products alternative energy segment:
Ethanol		76	%		81	%		77	%		81	%
Distillers grains		21	%		19	%		20	%		19	%
Other		3	%		—	%		3	%		—	%

Total		100	%		100	%		100	%		100	%


Sales of services real estate segment:
Lease revenue		100	%		100	%		100	%		100	%

Certain corporate costs and expenses, including information technology, employee benefits and other shared services are allocated to the business segments. The allocations are generally amounts agreed upon by management and are based on a reasonable and systematic approach, which may differ from amounts that would be incurred if such services were purchased separately by the business segment. Corporate assets are primarily cash and deferred income tax benefits.

Cash, except for cash held by One Earth and NuGen, is considered to be fungible and available for both corporate and segment use depending on liquidity requirements. Cash of approximately $15.9 million held by One Earth and NuGen will be used primarily to fund working capital needs for the subsidiaries.

Note 16. Related-Party Transactions

During the second quarters of fiscal year 2012 and 2011, One Earth purchased approximately $64.4 million and approximately $58.4 million, respectively, of corn from the Alliance Grain Elevator, an equity investor in One Earth. Such purchases totaled approximately $120.9 million and approximately $127.8 million for the six months ended July 31, 2012 and 2011, respectively.

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

Historically, we were a specialty retailer in the consumer electronics/appliance industry serving small to medium-sized towns and communities. In addition, we have been an investor in various alternative energy entities beginning with synthetic fuel partnerships in 1998 and later ethanol production facilities beginning in 2006.

We completed our exit of the retail business as of July 31, 2009. Going forward, we expect that our only retail related activities will consist of the administration of previously sold extended service plans and the payment of related claims. All activities related to extended service plans are classified as discontinued operations.

In addition, we have owned real estate remaining from our former retail store operations.

The real estate consists of 19 former retail stores and one distribution center which we include in our real estate segment.

At July 31, 2012, we had equity investments in four ethanol limited liability companies, two of which we have a majority ownership interest in. We may consider making additional investments in the alternative energy segment during fiscal year 2012. The following table is a summary of ethanol gallons shipped at our plants at July 31, 2012:


Entity	Trailing 12 Months Ethanol Gallons Shipped			REX’s Current Ownership Interest			Current Effective Ownership of Trailing 12 Months Ethanol Gallons Shipped

One Earth Energy, LLC		106.6	M		74	%		78.9	M
NuGen Energy, LLC		112.9	M		99	%		111.8	M
Patriot Holdings, LLC		114.0	M		27	%		30.8	M
Big River Resources W Burlington, LLC		101.9	M		10	%		10.2	M
Big River Resources Galva, LLC		105.2	M		10	%		10.5	M
Big River United Energy, LLC		111.9	M		5	%		5.6	M
Big River Resources Boyceville, LLC (1)		33.4	M		10	%		3.3	M

Total		685.9	M					251.1	M


	(1)	Our current effective annual gallons sold represents seven months of ownership of Big River Resources Boyceville, LLC.

Our ethanol operations are highly dependent on commodity prices, especially prices for corn, ethanol, distillers grains 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, at times ethanol prices may lag movements in corn prices and, in an environment of higher 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 difference between the price per gallon of ethanol and the price per bushel of grain (divided by 2.8) 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 expect these decisions to be made on an individual plant basis, as there are different market conditions at each of our ethanol plants.

We attempt to manage the risk related to the volatility of grain and ethanol prices by utilizing forward grain purchase and forward ethanol and distillers grains sale contracts. We attempt to match quantities of ethanol and distillers grains sale contracts with an appropriate quantity of grain purchase contracts over a given period of time when we can obtain an adequate gross margin resulting from the crush spread inherent in the contracts we have executed. However, the market for future ethanol sales contracts is not a mature market. Consequently, we generally execute contracts for no more than three months into the future at any given 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 three months; thus, we are unable to predict the likelihood or amounts of future income or loss from the operations of our ethanol facilities.

Critical Accounting Policies and Estimates

During the three months ended July 31, 2012, we did not change any of our critical accounting policies as disclosed in our 2011 Annual Report on Form 10-K as filed with the Securities and Exchange Commission on April 9, 2012. All other accounting policies used in preparing our interim fiscal year 2012 Consolidated Condensed Financial Statements are the same as those described in our Form 10-K.

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 2012” means the period February 1, 2012 to January 31, 2013.

Results of Operations

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

Comparison of Three Months and Six Months Ended July 31, 2012 and 2011

Net sales and revenue in the quarter ended July 31, 2012 were approximately $153.2 million compared to approximately $73.8 million in the prior year’s second quarter, representing an increase of approximately $79.4 million. Net sales and revenue do not include sales from real estate operations classified as discontinued operations. The increase was primarily caused by higher sales in our alternative energy segment of approximately $79.2 million. Net sales and revenue from our real estate segment were approximately $0.4 million in the second quarter of fiscal year 2012 and approximately $0.3 million in the second quarter of fiscal year 2011.

Net sales and revenue for the first six months of fiscal year 2012 were approximately $304.2 million compared to approximately $155.0 million for the first six months of fiscal year 2011. This represents an increase of approximately $149.2 million. The increase was primarily caused by higher sales in our alternative energy segment of approximately $149.0 million.

The following table reflects the approximate percent of net sales for each major product and service group for the following periods:


	Three Months Ended July 31,						Six Months Ended July 31,
Product Category	2012			2011			2012			2011

Ethanol		76	%		81	%		77	%		81	%
Distillers grains		21			19			20			19
Other		3			—			3			—

Total		100	%		100	%		100	%		100	%

Gross profit for the second quarter of fiscal year 2012 was approximately $6.8 million (4.4% of net sales and revenue) which was approximately $7.0 million higher compared to approximately $0.2 million of gross loss (0.3% of net sales and revenue) for the second quarter of fiscal year 2011. Gross profit for the second quarter of fiscal year 2012 increased by approximately $6.1 million compared to the prior year from our alternative energy segment. Real estate segment gross loss for the second quarter of fiscal year 2012 decreased by approximately $0.9 million compared to the prior year.

Gross profit for the first six months of fiscal year 2012 was approximately $12.3 million (4.0% of net sales and revenue) which was approximately $7.7 million higher compared to approximately $4.5 million (2.9% of net sales and revenue) for the first six months of fiscal year 2011. Gross profit for the six months ended July 31, 2012 increased by approximately $6.8 million compared to the prior year as a result of operations in the alternative energy segment. Gross loss for the first six months of fiscal year 2012 decreased by approximately $0.9 million compared to the prior year from our real estate segment.

Selling, general and administrative expenses for the second quarter of fiscal year 2012 were approximately $3.6 million (2.3% of net sales and revenue), an increase of approximately $1.6 million from approximately $2.0 million (2.7% of net sales and revenue) for the second quarter of fiscal year 2011. The increase was primarily caused by higher expenses in our alternative energy segment of approximately $1.6 million. Selling, general and administrative expenses were approximately $6.2 million (2.0% of net sales and revenue) for the first six months of fiscal year 2012 representing an increase of approximately $1.9 million from $4.3 million (2.8% of net sales and revenue) for the first six months of fiscal year 2011. For the first six months of fiscal year 2012, these expenses increased approximately $2.0 million compared to the prior year in the alternative energy segment.

During the second quarters of fiscal years 2012 and 2011, we recognized (loss) income of approximately $(0.5) million and $3.8 million, respectively, from our equity investments in Big River, Patriot and NuGen. During the first six months of fiscal years 2012 and 2011, we recognized (loss) income of approximately $(39,000) and $9.5 million, respectively, from these investments. Effective November 1, 2011, we acquired an additional 50% equity interest in NuGen, which operates an ethanol producing facility in Marion, South Dakota with an annual nameplate capacity of 100 million gallons. As of November 1, 2011, we ceased using the equity method of accounting for NuGen and began consolidating their results prospectively. We

acquired our initial 48% ownership interest in NuGen on July 1, 2010. We currently have a 99% equity interest in NuGen. Big River has an effective ownership of an annual nameplate capacity of 297 million gallons which consists of ownership of 100% of three plants with an annual nameplate capacity of 247 million gallons and ownership of 50% of a plant with an annual nameplate capacity of 100 million gallons in addition to owning several grain elevators. Patriot has one plant with an annual nameplate capacity of 100 million gallons.

Due to the inherent volatility of the crush spread, we cannot predict the likelihood of future operating results from Big River and Patriot being similar to historical results.

During the second quarter of fiscal year 2011, we recognized income of approximately $2.9 million from the sale of a synthetic fuel partnership we sold in fiscal year 2005. This income represents one final payment for synthetic fuel production occurring during fiscal year 2008. We will not recognize any additional income from this investment.

Interest income was approximately $41,000 and approximately $101,000 for the second quarter of fiscal years 2012 and 2011, respectively. Interest income was approximately $90,000 and approximately $271,000 for the first six months of fiscal years 2012 and 2011, respectively. The decline is primarily related to lower levels of excess cash invested and lower yields earned during fiscal year 2012 compared to the prior year.

Interest expense was approximately $1.2 million for the second quarter of fiscal year 2012 compared to approximately $0.6 million for the second quarter of fiscal year 2011, an increase of approximately $0.6 million. Interest expense was approximately $2.5 million for the first six months of fiscal year 2012 compared to approximately $1.3 million for the first six months of fiscal year 2011, an increase of approximately $1.2 million. These increases were primarily attributable to the alternative energy segment as we consolidated NuGen in fiscal year 2012 which had approximately $0.6 million of interest expense in the second quarter of fiscal year 2012 and approximately $1.2 million of interest expense for the first six months of fiscal year 2012.

We recognized losses of approximately $0.1 million and $0.8 million during the second quarter of fiscal years 2012 and 2011, respectively, related to forward interest rate swap agreements that One Earth entered into during fiscal year 2007. We recognized a loss related to the swaps of approximately $0.2 million during the first six months of fiscal year 2012 compared to approximately $0.7 million during the first six months of fiscal year 2011. In general, declining interest rates have a negative effect on our interest rate swaps and vice versa, as our swaps fixed the interest rate of variable rate debt. Should interest rates decline, we would expect to experience losses on the interest rate swaps. We would expect to incur gains on the interest rate swaps should interest rates increase. We cannot predict the future movements in interest rates; thus, we are unable to predict the likelihood or amounts of future gains or losses related to interest rate swaps.

As a result of the foregoing, income from continuing operations before income taxes was approximately $1.5 million for the second quarter of fiscal year 2012 versus approximately $3.2 million for the second quarter of fiscal year 2011. Income from continuing operations before

income taxes was approximately $3.4 million for the first six months of fiscal year 2012 versus approximately $10.9 million for the first six months of fiscal year 2011.

Our effective tax rate was 30.3% and 47.5% for the second quarter of fiscal years 2012 and 2011, respectively. Our effective tax rate for the first six months of fiscal year 2012 was 29.6% compared to 38.7% for the first six months of fiscal year 2011. The fluctuations in the effective tax rate primarily relate to the presentation of noncontrolling interests in the income or loss of consolidated subsidiaries as noncontrolling interests are presented in the Consolidated Condensed Statements of Operations after the income tax provision or benefit. The noncontrolling interests in the income/loss of One Earth and NuGen was a higher proportion of pre-tax income in fiscal year 2012 compared to the pre-tax income/loss of One Earth for fiscal year 2011.

As a result of the foregoing, income from continuing operations was approximately $1.1 million for the second quarter of fiscal year 2012 versus approximately $1.7 million for the second quarter of fiscal year 2011. Income from continuing operations was approximately $2.4 million for the first six months of fiscal year 2012 versus approximately $6.7 million for the first six months of fiscal year 2011.

During fiscal year 2009, we closed our remaining retail store and warehouse operations and reclassified all retail related results as discontinued operations. As a result of these closings and certain other retail store and real estate property closings, we had income from discontinued operations, net of tax, of approximately $0.2 million in the second quarter of fiscal year 2012 compared to approximately $0.3 million in the second quarter of fiscal year 2011. We had income from discontinued operations, net of tax, of approximately $0.3 million for the first six months of fiscal year 2012 compared to approximately $0.7 million for the first six months of fiscal year 2011. Two properties classified as discontinued operations were sold during the second quarter of fiscal year 2012, resulting in a gain, net of taxes of approximately $56,000 compared to approximately $40,000 during the second quarter of fiscal year 2011. Three properties classified as discontinued operations were sold during the first six months of fiscal year 2012, resulting in a gain, net of taxes of approximately $49,000 compared to approximately $174,000 during the first six months of fiscal year 2011.

Loss or (income) related to noncontrolling interests was approximately $(0.5) million and approximately $0.3 million during the second quarter of fiscal years 2012 and 2011, respectively, and approximately $(1.0) million and approximately $(0.6) million for the six months ended July 31, 2012 and 2011, respectively, and represents the owners’ (other than us) share of the income or loss of NuGen (fiscal year 2012) and One Earth (fiscal years 2012 and 2011).

As a result of the foregoing, net income attributable to REX common shareholders for the second quarter of fiscal year 2012 was approximately $0.8 million, a decrease of approximately $1.5 million from approximately $2.3 million for the second quarter of fiscal year 2011. Net income attributable to REX common shareholders for the first six months of fiscal year 2012 was approximately $1.7 million, a decrease of approximately $5.3 million from approximately $7.0 million for the first six months of fiscal year 2011.

Business Segment Results

We have two segments: alternative energy and real estate. The following sections discuss the results of operations for each of our business segments and corporate and other. As discussed in Note 15, our chief operating decision maker (as defined by ASC 280, “Segment Reporting”) evaluates the operating performance of our business segments using a measure we call segment profit. Segment profit includes gains and losses on derivative financial instruments. Segment profit excludes income taxes, indirect interest expense, discontinued operations, indirect interest income and certain other items that are included in net income determined in accordance with GAAP. Management believes these are useful financial measures; however, they should not be construed as being more important than other comparable GAAP measures.

Items excluded from segment profit generally result from decisions made by corporate executives. Financing, divestiture and tax structure decisions are generally made by corporate executives. Excluding these items from our business segment performance measure enables us to evaluate business segment operating performance based upon current economic conditions.

The following table sets forth, for the periods indicated, sales and profits by segment (amounts in thousands):


	Three Months Ended July 31,						Six Months Ended July 31,
	2012			2011			2012			2011

Net sales and revenue:
Alternative energy	$	152,778		$	73,531		$	303,442		$	154,413
Real estate		386			265			736			546

Total net sales and revenues	$	153,164		$	73,796		$	304,178		$	154,959


Segment gross profit (loss):
Alternative energy	$	7,027		$	952		$	12,537		$	5,730
Real estate		(233	)		(1,171	)		(277	)		(1,219	)

Total gross profit	$	6,794		$	(219	)	$	12,260		$	4,511


Segment profit (loss):
Alternative energy (1)	$	2,432		$	2,061		$	4,901		$	10,459
Real estate		(289	)		(1,218	)		(382	)		(1,331	)
Corporate expense		(623	)		(615	)		(1,136	)		(1,232	)
Interest expense		(21	)		(27	)		(45	)		(61	)
Income from synthetic fuel partnerships		—			2,883			—			2,883
Investment income		19			73			49			215

Income from continuing operations before income taxes	$	1,518		$	3,157		$	3,387		$	10,933


	(1)	Includes (loss) or income from equity method investments of $(481,000) and $3,761,000 in the quarters ended July 31, 2012 and 2011, respectively. Includes (loss)


	or income from equity method investments of $(39,000) and $9,543,000 in the six months ended July 31, 2012 and 2011, respectively.

Alternative Energy

The alternative energy segment includes the consolidated financial results of NuGen (fiscal year 2012) and One Earth (fiscal years 2012 and 2011), our equity method investments in ethanol facilities, the income related to those investments and certain administrative expenses. One Earth became fully operational during the third quarter of fiscal year 2009. Effective November 1, 2011, we obtained a controlling financial interest in NuGen. Thus, we began consolidating the results of NuGen prospectively as of the acquisition date. Prior to November 1, 2011, we used the equity method of accounting to account for the results of NuGen. The following table summarizes sales by product group (amounts in thousands):


	Three Months Ended July 31,				Six Months Ended July 31,
	2012		2011		2012		2011


Ethanol	$	116,476	$	59,452	$	233,791	$	125,510
Distillers grains		31,437		13,832		61,516		28,360
Non-food grade corn oil		4,357		—		7,222		—
Other		508		247		913		543

Total	$	152,778	$	73,531	$	303,442	$	154,413

The following table summarizes certain operating data:


	Three Months Ended July 31,				Six Months Ended July 31,
	2012		2011		2012		2011

Average selling price per gallon of ethanol	$	2.12	$	2.52	$	2.13	$	2.42
Average selling price per ton of dried distillers grains	$	216.95	$	192.81	$	206.99	$	189.01
Average cost per bushel of grain	$	6.49	$	6.57	$	6.46	$	6.85
Average cost of natural gas (per mmbtu)	$	3.32	$	4.37	$	3.72	$	4.38

Segment Results – Second Quarter Fiscal Year 2012 Compared to Second Quarter Fiscal Year 2011

Net sales and revenue increased approximately $79.2 million over the second quarter of fiscal year 2011 to approximately $152.8 million in the second quarter of fiscal year 2012, primarily a result of consolidating NuGen in fiscal year 2012. We accounted for the results of NuGen using the equity method of accounting until the fourth quarter of fiscal year 2011, at which time we obtained a controlling financial interest in NuGen, and

thus, began consolidating the results. Ethanol sales increased from approximately $59.5 million in the second quarter of fiscal year 2011 to approximately $116.5 million in the second quarter of fiscal year 2012. The average selling price per gallon of ethanol decreased from $2.52 in the second quarter of fiscal year 2011 to $2.12 in the second quarter of fiscal year 2012. This negative impact on sales was more than offset as our ethanol sales were based upon approximately 55.0 million gallons in the second quarter of fiscal year 2012 compared to 23.6 million gallons in the second quarter of fiscal year 2011. The increase in gallons of ethanol sold resulted primarily from including the results of NuGen in the current year but not in the prior year before consolidation. Distillers grains sales increased from approximately $13.8 million in the second quarter of fiscal year 2011 to approximately $31.4 million in the second quarter of fiscal year 2012. Two positive factors impacting distillers grains sales were that the average selling price per ton of dried distillers grains increased from $192.81 in the second quarter of fiscal year 2011 to $216.95 in the second quarter of fiscal year 2012 and that our dried distillers grains sales were based upon approximately 120,000 tons in the second quarter of fiscal year 2012 compared to approximately 71,000 tons in the second quarter of fiscal year 2011. The increase in tons of dried distillers grains sold resulted primarily from including the results of NuGen in the current year but not in the prior year before consolidation. Non-food grade corn oil sales were approximately $4.4 million in the second quarter of fiscal year 2012. The first quarter of fiscal year 2012 was the first period that our plants produced and sold non-food grade corn oil. We expect that net sales and revenue in future periods will be based upon production of 200 million to 230 million gallons of ethanol and 580,000 to 620,000 tons of dried distillers gains. This expectation assumes that One Earth and NuGen will operate at or near nameplate capacity, which is dependent upon the crush spread realized and operational factors.

Gross profit from these sales was approximately $7.0 million during the second quarter of fiscal year 2012 compared to approximately $1.0 million during the second quarter of fiscal year 2011. The crush spread for the second quarter of fiscal year 2012 was approximately ($0.20) per gallon of ethanol sold compared to the second quarter of fiscal year 2011 which was approximately $0.16 per gallon of ethanol sold. This trend was offset by the sales of distillers grains and non-food grade corn oil in the second quarter of fiscal year 2012. In addition, gross profit increased, in part as a result of including the results of NuGen in the current year but not in the prior year before consolidation. Grain accounted for approximately 85.3% ($124.3 million) of our cost of sales during the second quarter of fiscal year 2012 compared to approximately 82.3% ($59.7 million) during the second quarter of fiscal year 2011. Natural gas accounted for approximately 3.4% ($5.0 million) of our cost of sales during the second quarter of fiscal year 2012 compared to approximately 5.8% ($4.2 million) during the second quarter of fiscal year 2011. Given the inherent volatility in ethanol, distillers grains, non-food grade corn oil and grain 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 favorable or consistent compared to historical periods.

We attempt to match quantities of ethanol and distillers grains sale contracts with an appropriate quantity of grain purchase contracts over a given period of time when we

can obtain an adequate margin resulting from the crush spread inherent in the contracts we have executed. However, the market for future ethanol sales contracts is not a mature market. Consequently, we generally execute contracts for no more than three months into the future at any given 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 three months. Approximately 2% of our forecasted ethanol, approximately 7% of our forecasted distillers grains and approximately 3% 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 in fiscal year 2012 of approximately $60.1 million. Similarly, approximately 2% 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 current pricing would result in an increase in annual cost of goods sold in fiscal year 2012 of approximately $54.3 million.

Selling, general and administrative expenses were approximately $2.9 million in the second quarter of fiscal year 2012, a $1.6 million increase from approximately $1.3 million in the second quarter of fiscal year 2011. The increase is primarily a result of including the results of NuGen in the current year. NuGen incurred approximately $1.4 million of expenses in the second quarter of fiscal year 2012. We expect selling, general and administrative expenses to remain consistent with the second quarter of fiscal year 2012 results in future periods.

Interest expense increased approximately $0.6 million in the second quarter of fiscal year 2012 from the second quarter of fiscal year 2011 to approximately $1.2 million. This increase is primarily a result of consolidating NuGen beginning November 1, 2011 versus using the equity method of accounting for NuGen prior to November 1, 2011. Based on current interest rates, we expect interest expense in future quarters to be consistent with the second quarter of fiscal year 2012 amount based on current debt levels.

Income (loss) from equity method investments includes Big River, Patriot and NuGen for fiscal year 2011 and Big River and Patriot for fiscal year 2012 as we began consolidating the results of NuGen effective November 1, 2011. We recognized a loss from equity method investments of approximately $0.5 million in the second quarter of fiscal year 2012 compared to a gain of approximately $3.8 million in the second quarter of fiscal year 2011. We recognized approximately $0.1 million of income from Big River in the second quarter of fiscal year 2012 compared to approximately $1.6 million in the second quarter of fiscal year 2011. We recognized approximately $0.6 million of loss from Patriot in the second quarter of fiscal year 2012 compared to approximately $0.5 million of income in the second quarter of fiscal year 2011. We recognized approximately $1.7 million of income from NuGen in the second quarter of fiscal year 2011. In general, both Big River and Patriot experienced lower crush spreads in the second quarter of fiscal year 2012 relative to the second quarter of fiscal year 2011, which is consistent with industry trends. Given the inherent volatility in the factors that affect the crush spread, we cannot predict the likelihood that the trend with respect to income from equity method investments will be comparable in future periods.

Losses on derivative financial instruments held by One Earth were approximately $0.1 million in the second quarter of fiscal year 2012 compared to approximately $0.8 million in the second quarter of fiscal year 2011. Since the gains or losses on these derivative financial instruments are primarily a function of the movement in interest rates, we cannot predict the likelihood that such gains or losses in future periods will be consistent with current year results.

As a result of the factors discussed above, segment profit increased to approximately $2.4 million in the second quarter of fiscal year 2012 compared to approximately $2.1 million in the second quarter of fiscal year 2011.

Segment Results – Six Months Ended July 31, 2012 Compared to Six Months Ended July 31, 2011

Net sales and revenue increased approximately $149.0 million to approximately $303.4 million, primarily a result of consolidating NuGen in fiscal year 2012. We accounted for the results of NuGen using the equity method of accounting until the fourth quarter of fiscal year 2011, at which time we obtained a controlling financial interest in NuGen, and thus, began consolidating the results. Ethanol sales increased from approximately $125.5 million in the first six months of fiscal year 2011 to approximately $233.8 million in the first six months of fiscal year 2012. The average selling price per gallon of ethanol decreased from $2.42 in the first six months of fiscal year 2011 to $2.13 in the first six months of fiscal year 2012. This negative impact on sales was more than offset as our ethanol sales were based upon approximately 109.8 million gallons in the first six months of fiscal year 2012 compared to 51.8 million gallons in the first six months of fiscal year 2011. The increase in gallons of ethanol sold resulted primarily from including the results of NuGen in the current year but not in the prior year before consolidation. Distillers grains sales increased from approximately $28.4 million in the first six months of fiscal year 2011 to approximately $61.5 million in the first six month of fiscal year 2012. Two positive factors impacting distillers grains sales were that the average selling price per ton of dried distillers grains increased from $189.01 in the first six months of fiscal year 2011 to $206.99 in the first six months of fiscal year 2012 and that our dried distillers grains sales were based upon approximately 250,000 tons in the first six months of fiscal year 2012 compared to approximately 149,000 tons in the first six months of fiscal year 2011. The increase in tons of dried distillers grains sold resulted primarily from including the results of NuGen in the current year but not in the prior year before consolidation. Non-food grade corn oil sales were approximately $7.2 million in the first six months of fiscal year 2012. The first quarter of fiscal year 2012 was the first period that our plants produced and sold non-food grade corn oil.

Real Estate

The real estate segment includes all owned real estate including those previously used as retail store and distribution center operations, our real estate leasing activities and certain administrative expenses. It excludes results from discontinued operations.

At July 31, 2012, we have lease agreements, as landlord, for six owned former retail stores (77,000 square feet leased). We have 13 owned former retail stores (167,000 square feet) that are vacant at July 31, 2012. We have seasonal (temporary) lease agreements, as landlord, for four of these owned properties. We are marketing these vacant properties for lease or sale. In addition, one owned former distribution center is partially leased (221,000 square feet), partially occupied by our corporate office personnel (10,000 square feet) and partially vacant (246,000 square feet).

Segment Results – Second Quarter Fiscal Year 2012 Compared to Second Quarter Fiscal Year 2011

Net sales and revenue of $386,000 increased $121,000 over the prior year amount of $265,000. The increase results primarily from three additional properties leased during fiscal year 2012 compared to fiscal year 2011. We expect lease revenue for the remainder of fiscal year 2012 to be consistent with the second quarter of fiscal year 2012 based upon leases currently executed.

Gross loss in the second quarter of fiscal year 2012 was $233,000 compared to $1,171,000 in the second quarter of fiscal year 2011. The decrease in gross loss compared to the prior year is primarily a result of impairment charges, incurred in fiscal year 2011, of approximately $1,153,000 related to a former distribution center, a portion of which is used as our corporate headquarters. We expect gross loss for the remainder of fiscal year 2012 to be consistent with the current year second quarter results based upon leases currently executed.

As a result of the factors discussed above, segment loss decreased to $289,000 in the second quarter of fiscal year 2012 from $1,218,000 in the second quarter of fiscal year 2011.

Segment Results – Six Months Ended July 31, 2012 Compared to Six Months Ended July 31, 2011

Net sales and revenue of $736,000 increased $190,000 over the prior year amount of $546,000. The increase results primarily from three additional properties leased during fiscal year 2012 compared to fiscal year 2011. We expect lease revenue for the remainder of fiscal year 2012 to be consistent with the first six months of fiscal year 2012 based upon leases currently executed.

Gross loss in the first six months of fiscal year 2012 was $277,000 compared to $1,219,000 in the first six months of fiscal year 2011. The decrease in gross loss compared to the prior year is primarily a result of impairment charges, incurred in fiscal year 2011, of approximately $1,153,000 related to a former distribution center, a portion of which is used as our corporate headquarters. We expect gross loss for the remainder of fiscal year 2012 to be consistent with the first six months of fiscal year 2012 based upon leases currently executed.

As a result of the factors discussed above, segment loss decreased to $382,000 in the first six months of fiscal year 2012 from $1,331,000 in the first six months of fiscal year 2011.

Corporate and Other

Corporate and other includes certain administrative expenses of the corporate headquarters, interest expense and investment income not directly allocated to the alternative energy or real estate segments.

Corporate and Other Results – Second Quarter Fiscal Year 2012 Compared to Second Quarter Fiscal Year 2011

Selling, general and administrative expenses were approximately $0.6 million in the second quarter of fiscal year 2012 consistent with the second quarter of fiscal year 2011. We expect selling, general and administrative expenses for the remainder of fiscal year 2012 to be consistent with the current year second quarter results.

Interest income was $19,000 in the second quarter of fiscal year 2012 compared to $73,000 in the second quarter of fiscal year 2011. The decrease is primarily a result of lower levels of excess cash invested and lower yields earned in the current year. We expect interest income for the remainder of fiscal year 2012 to be consistent with the current year second quarter results.

Interest expense was consistent with the prior year amount.

Corporate and Other Results – Six Months Ended July 31, 2012 Compared to Six Months Ended July 31, 2011

Selling, general and administrative expenses were approximately $1.1 million in the first six months of fiscal year 2012 consistent with the first six months of fiscal year 2011. We expect selling, general and administrative expenses for the remainder of fiscal year 2012 to be consistent with the current year second quarter results.

Interest income was $49,000 in the first six months of fiscal year 2012 compared to $215,000 in the first six months of fiscal year 2011. The decrease is primarily a result of lower levels of excess cash invested and lower yields earned in the current year. We expect interest income for the remainder of fiscal year 2012 to be consistent with the current year first quarter results.

Interest expense was consistent with the prior year amount.

Liquidity and Capital Resources

Net cash provided by operating activities was approximately $3.5 million for the first six months of fiscal year 2012, compared to approximately $12.9 million for the first six months of fiscal year 2011. For the first six months of fiscal year 2012, cash was provided by net income of approximately $2.8 million, adjusted for non-cash items of approximately $7.8 million, which consisted of depreciation and amortization, deferred income and the deferred income tax provision. Dividends received from our equity method investees were approximately $2.0 million

in the first six months of fiscal year 2012. An increase in accounts receivable represented a use of cash of approximately $2.1 million, primarily a result of normal variations in production and sales levels. Other liabilities used cash of approximately $4.0 million, primarily a result of the payment of incentive compensation that was accrued at year end. A decrease in accounts payable used cash of approximately $3.8 million, which is primarily a result of the timing of vendor shipments of inventory and vendor payments. A decrease in inventory provided cash of approximately $1.0 million, which is primarily a result of normal fluctuations in production and sales levels.

Net cash provided by operating activities was approximately $12.9 million for the first six months of fiscal year 2011. For the first six months of fiscal year 2011, cash was provided by net income of $7.6 million, adjusted for non-cash items of $(5.9) million, which consisted of depreciation and amortization, impairment charges, income from equity method and synthetic fuel investments, deferred income, losses on derivative financial instruments, the deferred income tax provision and other items. Dividends received from our equity method investees were $2.3 million in the first six months of fiscal year 2011. In addition, prepaid expense and other current and long term assets provided cash of $9.9 million, primarily a result of federal income tax refunds received. Accounts receivable provided cash of $1.7 million, a result of normal variations in production and sales levels. Other liabilities provided cash of approximately $1.7 million, generally a result of normal variations in accrued liabilities. The primary uses of cash were an increase in inventory of $2.6 million and a decrease in accounts payable of $1.7 million. These fluctuations were the result of normal variations in production, purchasing and grain prices.

At July 31, 2012, working capital was approximately $90.4 million compared to approximately $89.8 million at January 31, 2012. This increase is primarily a result of operating cash flows. The ratio of current assets to current liabilities was 4.4 to 1 at July 31, 2012 and 3.4 to 1 at January 31, 2012.

Cash of approximately $0.6 million was provided by investing activities for the first six months of fiscal year 2012, compared to approximately $3.8 million during the first six months of fiscal year 2011. During the first six months of fiscal year 2012, we had capital expenditures of approximately $2.3 million, primarily related to improvements at the One Earth ethanol plant. One Earth and NuGen expect to spend a combined range of approximately $1.0 million to $2.0 million during the remainder of fiscal year 2012 on various projects at their plants. We received approximately $2.2 million as proceeds from the sale of three real estate properties during the first six months of fiscal year 2012. We also received approximately $0.7 million as we were able to reduce the amount of our restricted investments on deposit with the state of Florida to secure our extended service plan obligations.

Cash of approximately $3.8 million was provided by investing activities for the first six months of fiscal year 2011. During the first six months of fiscal year 2011, we had capital expenditures of approximately $0.6 million, primarily related to improvements at the One Earth ethanol plant. We received a payment of $2.8 million related to the final settlement of a synthetic fuel partnership sale during the first six months of fiscal year 2011. We will not receive additional money related to sales of synthetic fuel partnerships. We received approximately $1.6 million as proceeds from the sale of three real estate properties during the first six months of fiscal year 2011.

Cash used in financing activities totaled approximately $15.1 million for the first six months of fiscal year 2012 compared to approximately $11.3 million for the first six months of fiscal year 2011. Cash was used by debt payments of approximately $11.0 million, primarily on One Earth’s and NuGen’s term loans. We used cash of approximately $2.0 million to purchase shares from and pay dividends to noncontrolling members of NuGen and One Earth. We do not expect such payments to noncontrolling members of NuGen or One Earth to increase significantly in fiscal year 2012. Stock option activity generated cash of approximately $0.4 million. In addition, cash of $2.5 million was used to repurchase approximately 137,000 shares of our common stock in open market transactions.

Cash used in financing activities totaled approximately $11.3 million for the first six months of fiscal year 2011. Cash of approximately $1.3 million was used to repay the contingent consideration liability related to our acquisition of NuGen. Cash was used by debt payments of $5.1 million, primarily on One Earth’s term loans. Stock option activity generated cash of $0.3 million. We used $3.2 million to repurchase 192,000 shares of our common stock in open market transactions during the first six months of fiscal year 2011. We used cash of $2.0 million to purchase shares from and pay dividends to noncontrolling shareholders of One Earth.

We believe we have sufficient working capital and credit availability to fund our commitments and to maintain our operations at their current levels for the next twelve months and foreseeable future.

Forward-Looking Statements

This Form 10-Q contains or may contain forward-looking statements as defined in the Private Securities Litigation Reform Act of 1995. Such statements can be identified by use of forward-looking terminology such as “may,” “expect,” “believe,” “estimate,” “anticipate” or “continue” or the negative thereof or other variations thereon or comparable terminology. Readers are cautioned that there are risks and uncertainties that could cause actual events or results to differ materially from those referred to in such forward-looking statements. These risks and uncertainties include the risk factors set forth from time to time in the Company’s filings with the Securities and Exchange Commission and include among other things: the impact of legislative changes, the price volatility and availability of corn, distillers grains, ethanol, non-food grade corn oil, gasoline, natural gas, ethanol plants operating efficiently and according to forecasts and projections, changes in the national or regional economies, weather, the effects of terrorism or acts of war and changes in real estate market conditions. 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, 2012 (File No. 001-09097).

Item 3. Quantitative and Qualitative Disclosures About Market Risk

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

Interest Rate Risk

We are exposed to market risk from changes in interest rates. Interest rate risk related to interest income is immaterial. Exposure to interest rate risk results primarily from holding term and revolving loans that bear variable interest rates. Specifically, we have approximately $111.8 million outstanding in debt as of July 31, 2012, that is variable-rate. Of this amount, approximately $39.9 million is fixed by an interest rate swap. Interest rates on our variable-rate debt are determined based upon the market interest rate of LIBOR plus 280 to 325 basis points. A 10% adverse change (for example from 3.0% to 3.3%) in market interest rates would increase our interest cost on such debt by approximately $360,000 over the term of the debt. However, this change would be greater should LIBOR rates exceed 0.75%, as the floor interest rate of NuGen’s debt is the greater of 4% or LIBOR plus 325 basis points.

One Earth entered into a forward interest rate swap in the notional amount of $50.0 million with the First National Bank of Omaha during fiscal year 2007. The swap fixed the variable interest rate of a portion of One Earth’s term loan at 7.9%. The swap settlements commenced on July 31, 2009 and terminate on July 8, 2014. A hypothetical 10% change (for example, from 4.0% to 3.6%) in market interest rates at quarter end would change the fair value of the interest rate swap by approximately $0.4 million.

Commodity Price Risk

We manage a portion of our risk with respect to the volatility of commodity prices inherent in the ethanol industry by using forward purchase and sale contracts. At July 31, 2012, One Earth and NuGen combined have purchase commitments for approximately 7.3 million bushels of corn, the principal raw material for their ethanol plants. One Earth and NuGen expect to take delivery of the corn through September 2012. At July 31, 2012, One Earth and NuGen have combined sales commitments for approximately 59.8 million gallons of ethanol, approximately 53,000 tons of distillers grains and approximately 1.3 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 December 2012. Approximately 2% 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 $44.9 million for the remaining forecasted ethanol sales. Approximately 7% 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 $13.7 million for the remaining forecasted distillers grains sales. Approximately 3% 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 $1.5 million for the remaining forecasted non-food grade corn oil sales. Similarly, approximately 2% of our estimated corn usage for the next 12 month was subject to fixed-price contracts. As a result, the effect of a 10% adverse move in the price of corn for current pricing would result in an increase in annual cost of goods sold of approximately $54.3 million for the remaining forecasted corn usage.

Item 4. Controls and Procedures

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

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

PART II. OTHER INFORMATION

Item 1. Legal Proceedings

We are not party to any legal proceedings that we believe would, individually or in the aggregate, have a material adverse effect on our financial condition, results of operations or cash flows.

Item 1A. Risk Factors

The following risk factor, which modifies the risk factors set forth in our Annual Report on Form 10-K for the year ended January 31, 2012, should be considered in conjunction with the other information included in, or incorporated by reference in, this Quarterly Report on Form 10-Q.

Governors of several states have petitioned the United States Environmental Protection Agency (“EPA”) to waive the applicable volume requirements of the Renewable Fuel Standard (“RFS”). This petition is based upon drought conditions in portions of the United States, crop price increases and the severe economic harm it would cause to their states. Other organizations and individuals have also submitted letters requesting the EPA to waive the applicable volume requirements of the RFS or expressing support for the granting of a volume waiver. The EPA on August 20, 2012, said it had begun weighing requests to suspend the United States ethanol mandate, which requires refiners to blend ethanol into gasoline and is seeking public feedback. The waiver of, or any other modification which lowers the volume requirements of the RFS could have a material adverse effect on our ethanol business.

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 second quarter of fiscal year 2012, One Earth paid dividends of $5,490,000. Of this amount, $1,429,000 was paid to noncontrolling interests unit holders and $4,061,000 was paid to REX American Resources Corporation.

Issuer Purchases of Equity Securities


Period	Total Number of Shares Purchased		Average Price Paid per Share		Total Number of Shares Purchased as Part of Publicly Announced Plans or Programs		Maximum Number of Shares that May Yet Be Purchased Under the Plans or Programs (1)

May 1-31, 2012		—	$	—		—		162,455
June 1-30, 2012		83,154		17.93		83,154		79,301
July 1-31, 2012		54,328		18.02		54,328		24,973

Total		137,482	$	17.97		137,482		24,973


	(1)	On October 20, 2011, our Board of Directors increased our share repurchase authorization by an additional 500,000 shares. At July 31, 2012, a total of 24,973 shares remained available to purchase under this authorization.

Item 3. Defaults upon Senior Securities

None

Item 4. Mine Safety Disclosures

None

Item 5. Other Information

None

Item 6. Exhibits.

The following exhibits are filed with this report:


	4(a)	Sixth Amendment of Construction Loan Agreement dated May 30, 2012 among One Earth Energy, LLC, First National Bank of Omaha, as a Bank and as Administrative Agent, Accounts Bank and Collateral Agent, and the other Banks party thereto

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

	32	Section 1350 Certifications

	101	The following information from REX American Resources Corporation Quarterly Report on Form 10-Q for the quarter ended July 31, 2012, 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.

SIGNATURES

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


	REX American Resources Corporation
	Registrant


Signature	Title	Date


/s/ Stuart A. Rose	Chairman of the Board
	(Chief Executive Officer)	September 5, 2012
(Stuart A. Rose)

/s/ Douglas L. Bruggeman	Vice President, Finance and Treasurer
	(Chief Financial Officer)	September 5, 2012
(Douglas L. Bruggeman)