10-Q

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

Quarterly Report Pursuant to Section 13 or 15(d) of

the Securities Exchange Act of 1934

For the Quarterly Period Ended March 31, 2012

Commission File Number 001-32924

GREEN PLAINS RENEWABLE ENERGY, INC.

(Exact name of registrant as specified in its charter)

Iowa	84-1652107
(State or other jurisdiction of incorporation or organization)	(I.R.S. Employer Identification No.)
450 Regency Parkway, Suite 400, Omaha, NE 68114	(402) 884-8700
(Address of principal executive offices, including zip code)	(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.    x  Yes    ¨  No

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 (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files).    x  Yes    ¨  No

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 the definitions of “large accelerated filer,” “accelerated filer” and “smaller reporting company” in Rule 12b-2 of the Exchange Act.

Large accelerated filer	¨	Accelerated filer	x
Non-accelerated filer	¨	Smaller reporting company	¨

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

The number of shares of common stock, par value $0.001 per share, outstanding as of April 27, 2012 was 29,583,902 shares.

TABLE OF CONTENTS

		Page
PART I – FINANCIAL INFORMATION
Item 1.	Financial Statements
	Consolidated Balance Sheets		2
	Consolidated Statements of Operations		3
	Consolidated Statements of Comprehensive Income (Loss)		4
	Consolidated Statements of Cash Flows		5
	Notes to Consolidated Financial Statements		7
Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations		24
Item 3.	Quantitative and Qualitative Disclosures About Market Risk		36
Item 4.	Controls and Procedures		38
PART II – OTHER INFORMATION
Item 1.	Legal Proceedings		39
Item 1A.	Risk Factors		39
Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds		41
Item 3.	Defaults Upon Senior Securities		41
Item 4.	Mine Safety Disclosures		41
Item 5.	Other Information		41
Item 6.	Exhibits		42
Signatures			43

1

GREEN PLAINS RENEWABLE ENERGY, INC. AND SUBSIDIARIES

CONSOLIDATED BALANCE SHEETS

(in thousands, except share amounts)

	March 31,			December 31,
	2012			2011
	(unaudited)
ASSETS
Current assets
Cash and cash equivalents	$	134,989		$	174,988
Restricted cash		24,823			19,619
Accounts receivable, net of allowances of $309 and $263, respectively		92,702			106,198
Inventories		250,925			229,070
Prepaid expenses and other		5,715			8,610
Deferred income taxes		25,634			14,828
Deposits		3,665			5,679
Derivative financial instruments		28,363			17,428
Total current assets		566,816			576,420
Property and equipment, net of accumulated depreciation of $138,809 and $125,798, respectively		770,298			776,789
Goodwill		40,877			40,877
Other assets		25,695			26,742
Total assets	$	1,403,686		$	1,420,828
LIABILITIES AND STOCKHOLDERS’ EQUITY
Current liabilities
Accounts payable	$	96,852		$	172,328
Accrued and other liabilities		24,685			29,825
Unearned revenue		18,198			15,453
Short-term borrowings		169,603			69,599
Current maturities of long-term debt		83,787			73,760
Total current liabilities		393,125			360,965
Long-term debt		486,319			493,407
Deferred income taxes		60,294			55,970
Other liabilities		4,948			5,129
Total liabilities		944,686			915,471
Stockholders’ equity
Common stock, $0.001 par value; 75,000,000 shares authorized; 36,790,315 and 36,413,611 shares issued, and 29,590,315 and 32,913,611 shares outstanding, respectively		37			36
Additional paid-in capital		441,781			440,469
Retained earnings		83,069			95,761
Accumulated other comprehensive loss		(320	)		(2,953	)
Treasury stock, 7,200,000 and 3,500,000 shares, respectively		(65,808	)		(28,201	)
Total Green Plains stockholders’ equity		458,759			505,112
Noncontrolling interests		241			245
Total stockholders’ equity		459,000			505,357
Total liabilities and stockholders’ equity	$	1,403,686		$	1,420,828

See accompanying notes to the consolidated financial statements.

2

GREEN PLAINS RENEWABLE ENERGY, INC. AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF OPERATIONS

(unaudited and in thousands, except per share amounts)

	Three Months Ended March  31,
	2012			2011
Revenues	$	775,395		$	812,327
Cost of goods sold		766,625			774,703
Gross profit		8,770			37,624
Selling, general and administrative expenses		19,861			17,628
Operating income (loss)		(11,091	)		19,996
Other income (expense)
Interest income		39			91
Interest expense		(9,067	)		(8,132	)
Other, net		(578	)		(63	)
Total other expense		(9,606	)		(8,104	)
Income (loss) before income taxes		(20,697	)		11,892
Income tax expense (benefit)		(8,001	)		4,361
Net income (loss)		(12,696	)		7,531
Net loss attributable to noncontrolling interests		4			210
Net income (loss) attributable to Green Plains	$	(12,692	)	$	7,741
Earnings per share:
Income (loss) attributable to Green Plains stockholders - basic	$	(0.39	)	$	0.21
Income (loss) attributable to Green Plains stockholders - diluted	$	(0.39	)	$	0.20
Weighted average shares outstanding:
Basic		32,238			36,199
Diluted		32,238			42,764

See accompanying notes to the consolidated financial statements.

3

GREEN PLAINS RENEWABLE ENERGY, INC. AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS)

(unaudited and in thousands)

	Three Months Ended March  31,
	2012			2011
Net income (loss)	$	(12,696	)	$	7,531
Other comprehensive income (loss), net of tax:
Unrealized gains (losses) on derivatives arising during period, net of tax (expense) benefit of $(25) and $2,964, respectively		43			(4,589	)
Reclassification of realized losses on derivatives included in net income (loss), net of tax benefit of $1,491 and $364 respectively		2,590			549
Other comprehensive income (loss)		2,633			(4,040	)
Comprehensive income (loss)		(10,063	)		3,491
Comprehensive loss attributable to noncontrolling interests		4			210
Comprehensive income (loss) attributable to Green Plains	$	(10,059	)	$	3,701

See accompanying notes to the consolidated financial statements.

4

GREEN PLAINS RENEWABLE ENERGY, INC. AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF CASH FLOWS

(unaudited and in thousands)

	Three Months Ended March  31,
	2012			2011
Cash flows from operating activities:
Net income (loss)	$	(12,696	)	$	7,531
Adjustments to reconcile net income (loss) to net cash used by operating activities:
Depreciation and amortization		13,158			12,003
Amortization of debt issuance costs		775			578
Deferred income taxes		(6,482	)		1,617
Stock-based compensation expense		1,171			1,101
Undistributed equity in loss of affiliates		578			63
Allowance for doubtful accounts		46			14
Changes in operating assets and liabilities before effects of business combinations:
Accounts receivable		13,534			(226	)
Inventories		(21,477	)		(26,454	)
Deposits		2,014			(2,549	)
Derivative financial instruments		(8,264	)		(7,797	)
Prepaid expenses and other assets		2,895			(3,559	)
Accounts payable and accrued liabilities		(80,716	)		(77,751	)
Unearned revenues		2,745			4,326
Other		(172	)		(92	)
Net cash used by operating activities		(92,891	)		(91,195	)
Cash flows from investing activities:
Purchases of property and equipment		(5,660	)		(11,570	)
Acquisition of businesses, net of cash acquired		(1,490	)		(6,106	)
Other		—			(468	)
Net cash used by investing activities		(7,150	)		(18,144	)
Cash flows from financing activities:
Proceeds from the issuance of long-term debt		16,000			67,004
Payments of principal on long-term debt		(13,080	)		(91,226	)
Proceeds from short-term borrowings		782,086			853,205
Payments on short-term borrowings		(710,653	)		(818,237	)
Payments for repurchase of common stock		(10,445	)		—
Change in restricted cash		(5,204	)		17,628
Payments of loan fees		(292	)		(402	)
Other		1,630			45
Net cash provided by financing activities		60,042			28,017
Net change in cash and cash equivalents		(39,999	)		(81,322	)
Cash and cash equivalents, beginning of period		174,988			233,205
Cash and cash equivalents, end of period	$	134,989		$	151,883

Continued on the following page

5

GREEN PLAINS RENEWABLE ENERGY, INC. AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF CASH FLOWS

(unaudited and in thousands)

Continued from the previous page

	Three Months Ended March 31,
	2012			2011
Supplemental disclosures of cash flow:
Cash paid for income taxes	$	457		$	441
Cash paid for interest	$	7,032		$	7,884
Supplemental noncash investing and financing activities:
Assets acquired in acquisitions and mergers	$	1,590		$	61,015
Less: liabilities assumed		(100	)		(54,909	)
Net assets acquired	$	1,490		$	6,106
Short-term note payable issued to repurchase common stock	$	27,162		$	—

See accompanying notes to the consolidated financial statements.

6

GREEN PLAINS RENEWABLE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(unaudited)

1. BASIS OF PRESENTATION, DESCRIPTION OF BUSINESS AND SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

References to the Company

References to “Green Plains” or the “Company” in the consolidated financial statements and in these notes to the consolidated financial statements refer to Green Plains Renewable Energy, Inc., an Iowa corporation, and its subsidiaries.

Consolidated Financial Statements

The consolidated financial statements include the accounts of the Company, its wholly-owned subsidiaries and entities which it controls. All significant intercompany balances and transactions have been eliminated on a consolidated basis for reporting purposes. Unconsolidated entities are included in the financial statements on an equity basis. Certain amounts previously reported have been reclassified to conform to the current period presentation. Results for the interim periods presented are not necessarily indicative of results to be expected for the entire year.

The accompanying unaudited consolidated financial statements have been prepared in conformity with U.S. generally accepted accounting principles, or GAAP, for interim financial information and the instructions to Form 10-Q and Article 10 of Regulation S-X. Accordingly, they do not include all of the information and footnotes required by GAAP for complete financial statements. The financial statements should be read in conjunction with the Company’s annual report filed on Form 10-K for the year ended December 31, 2011.

The unaudited financial information reflects all adjustments which are, in the opinion of management, necessary for a fair presentation of the results of operations, financial position and cash flows for the periods presented. The adjustments are of a normal recurring nature, except as otherwise noted.

Use of Estimates in the Preparation of Consolidated Financial Statements

The preparation of consolidated financial statements in conformity with GAAP requires management to make certain estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the consolidated financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates.

Description of Business

Green Plains is North America’s fourth largest ethanol producer. The Company markets and distributes approximately one billion gallons of ethanol on an annual basis, including 740 million gallons per year, or mmgy, of production capacity from its nine ethanol plants. The Company also markets corn oil and distillers grains produced at its ethanol plants. Additionally, the Company owns and operates grain handling and storage assets and provides complementary agronomy services to local grain producers through its agribusiness segment. The Company owns and operates nine blending and terminaling facilities with approximately 625 mmgy of total throughput capacity. The Company is a partner in a joint venture that was formed to commercialize advanced photo-bioreactor technologies for the growing and harvesting of algal biomass.

Revenue Recognition

The Company recognizes revenue when all of the following criteria are satisfied: persuasive evidence of an arrangement exists; risk of loss and title transfer to the customer; the price is fixed and determinable; and collectability is reasonably assured.

For sales of ethanol and distillers grains by the Company’s marketing business, revenue is recognized when title to the product and risk of loss transfer to an external customer. Revenues related to marketing operations for third parties are recorded on a gross basis in the consolidated financial statements as Green Plains Trade takes title to the product and assumes risk of loss. Unearned revenue is reflected on the consolidated balance sheets for goods in transit for which the Company has received payment and title has not been transferred to the customer. Revenues from BlendStar’s biofuel terminal operations, which include ethanol transload and splash blending services, are recognized as these services are rendered.

7

The Company routinely enters into fixed-price, physical-delivery ethanol sales agreements. In certain instances, the Company intends to settle the transaction by open market purchases of ethanol rather than by delivery from its own production. These transactions are reported net as a component of revenues. Revenues also include realized gains and losses on related derivative financial instruments, ineffectiveness on cash flow hedges, and reclassifications of realized gains and losses on effective cash flow hedges from accumulated other comprehensive income (loss).

Sales of agricultural commodities, fertilizers and other similar products are recognized when title to the product and risk of loss transfer to the customer, which is dependent on the agreed upon sales terms with the customer. These sales terms provide for passage of title either at the time shipment is made or at the time the commodity has been delivered to its destination and final weights, grades and settlement prices have been agreed upon with the customer. Shipping and handling costs are presented gross in the statements of operations with amounts billed included in revenues and also as a component of cost of goods sold. Revenues from grain storage are recognized as services are rendered. Revenues related to grain merchandising are presented gross.

Cost of Goods Sold

Cost of goods sold includes costs for direct labor, materials and certain plant overhead costs. Direct labor includes all compensation and related benefits of non-management personnel involved in the operation of the Company’s ethanol plants. Grain purchasing and receiving costs, other than labor costs for grain buyers and scale operators, are also included in cost of goods sold. Direct materials consist of the costs of corn feedstock, denaturant, and process chemicals. Corn feedstock costs include unrealized gains and losses on related derivative financial instruments not designated as cash flow hedges, inbound freight charges, inspection costs and transfer costs. Corn feedstock costs also include realized gains and losses on related derivative financial instruments, ineffectiveness on cash flow hedges, and reclassifications of realized gains and losses on effective cash flow hedges from accumulated other comprehensive income (loss). Plant overhead costs primarily consist of plant utilities, plant depreciation and outbound freight charges. Shipping costs incurred directly by the Company, including railcar lease costs, are also reflected in cost of goods sold.

The Company uses exchange-traded futures and options contracts to minimize the effects of changes in the prices of agricultural commodities on its agribusiness segment’s grain inventories and forward purchase and sales contracts. Exchange-traded futures and options contracts are valued at quoted market prices. Commodity inventories, forward purchase contracts and forward sale contracts in the agribusiness segment are valued at market prices, where available, or other market quotes adjusted for differences, primarily transportation, between the exchange-traded market and the local markets on which the terms of the contracts are based. Changes in the market value of grain inventories, forward purchase and sale contracts, and exchange-traded futures and options contracts in the agribusiness segment, are recognized in earnings as a component of cost of goods sold. These contracts are predominantly settled in cash. The Company is exposed to loss in the event of non-performance by the counter-party to forward purchase and forward sales contracts.

Derivative Financial Instruments

To minimize the risk and the effects of the volatility of commodity price changes primarily related to corn, ethanol and natural gas, the Company uses various derivative financial instruments, including exchange-traded futures, and exchange-traded and over-the-counter options contracts. The Company monitors and manages this exposure as part of its overall risk management policy. As such, the Company seeks to reduce the potentially adverse effects that the volatility of these markets may have on its operating results. The Company may take hedging positions in these commodities as one way to mitigate risk. While the Company attempts to link its hedging activities to purchase and sales activities, there are situations where these hedging activities can themselves result in losses.

By using derivatives to hedge exposures to changes in commodity prices, the Company has exposures on these derivatives to credit and market risk. The Company is exposed to credit risk that the counterparty might fail to fulfill its performance obligations under the terms of the derivative contract. The Company minimizes its credit risk by entering into transactions with high quality counterparties, limiting the amount of financial exposure it has with each counterparty and monitoring the financial condition of its counterparties. Market risk is the risk that the value of the financial instrument might be adversely affected by a change in commodity prices or interest rates. The Company manages market risk by incorporating monitoring parameters within its risk management strategy that limit the types of derivative instruments and derivative strategies the Company uses, and the degree of market risk that may be undertaken by the use of derivative instruments.

8

The Company evaluates its contracts that involve physical delivery to determine whether they may qualify for the normal purchases or normal sales exemption and are expected to be used or sold over a reasonable period in the normal course of business. Any contracts that do not meet the normal purchase or sales criteria are recorded at fair value with the change in fair value recorded in operating income unless the contracts qualify for, and the Company elects, hedge accounting treatment.

Certain qualifying derivatives within the ethanol production segment are designated as cash flow hedges. Prior to entering into cash flow hedges, the Company evaluates the derivative instrument to ascertain its effectiveness. For cash flow hedges, any ineffectiveness is recognized in current period results, while other unrealized gains and losses are reflected in accumulated other comprehensive income until gains and losses from the underlying hedged transaction are realized. In the event that it becomes probable that a forecasted transaction will not occur, the Company would discontinue cash flow hedge treatment, which would affect earnings. These derivative financial instruments are recognized in current assets or other current liabilities at fair value.

The Company hedges its exposures to changes in the value of ethanol inventory and designates certain qualifying derivatives as fair value hedges. The carrying amount of the hedged inventory is adjusted through current period results for changes in the fair value arising from changes in ethanol prices. Any ineffectiveness is recognized in current period results to the extent that the change in the fair value of the inventory is not offset by the change in the fair value of the derivative.

Recent Accounting Pronouncements

Effective January 1, 2012, the Company adopted the third phase of amended guidance in ASC Topic 820, Fair Value Measurements and Disclosures. The amended guidance clarifies the application of existing fair value measurement 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 Company currently is not impacted by the additional disclosure requirements as it does not have any recurring Level 3 measurements.

Effective January 1, 2012, the Company adopted the amended guidance in ASC Topic 220, Comprehensive Income. This accounting standards update is aimed at increasing the prominence of other comprehensive income in the financial statements by eliminating the option to present other comprehensive income in the statement of stockholders’ equity. The Company has elected to present net income and other comprehensive income in two separate but consecutive statements. The updated presentation, which has been implemented retroactively for all comparable periods presented, did not impact the Company’s financial position or results of operations.

Effective January 1, 2012, the Company adopted the amended guidance in ASC Topic 350, Intangibles – Goodwill and Other. The amended guidance permits an entity to first assess qualitative factors to determine whether it is more likely than not that the fair value of a reporting unit is less than its carrying amount as a basis for determining whether it is necessary to perform the two-step goodwill impairment test. The more-likely-than-not threshold is defined as having a likelihood of more than 50 percent. The Company has determined that the changes to the accounting standards do not impact its disclosure or reporting requirements.

2. FAIR VALUE DISCLOSURES

The following methods, assumptions and valuation techniques were used in estimating the fair value of the Company’s financial instruments:

Level 1 – unadjusted quoted prices in active markets for identical assets or liabilities that the Company has the ability to access at the measurement date. Level 1 unrealized gains and losses on commodity derivatives relate to exchange-traded open trade equity and option values in the Company’s brokerage accounts.

Level 2 – directly or indirectly observable inputs such as quoted prices for similar assets or liabilities in active markets other than quoted prices included within Level 1; quoted prices for identical or similar assets in markets that are not active; and other inputs that are observable or can be substantially corroborated by observable market data by correlation or other means. Grain inventories held for sale in the agribusiness segment are valued at nearby futures values, plus or minus nearby basis levels.

Level 3 – unobservable inputs that are supported by little or no market activity and that are a significant component of the fair value of the assets or liabilities. The Company currently does not have any recurring Level 3 financial instruments.

9

There have been no changes in valuation techniques and inputs used in measuring fair value. The following tables set forth the Company’s assets and liabilities by level that were accounted for the periods indicated (in thousands):

	Fair Value Measurements at March 31, 2012
	Quoted Prices in Active Markets for Identical Assets		Significant Other Observable Inputs		Reclassification for Balance Sheet
	(Level 1)		(Level 2)		Presentation			Total
Assets
Cash and cash equivalents	$	134,989	$	—	$	—		$	134,989
Restricted cash		27,023		—		—			27,023
Margin deposits		22,783		—		—			22,783
Inventories carried at market		—		96,454		—			96,454
Unrealized gains on derivatives		3,225		11,079		(8,724	)		5,580
Total assets measured at fair value	$	188,020	$	107,533	$	(8,724	)	$	286,829
Liabilities
Unrealized losses on derivatives	$	8,951	$	7,231	$	(8,724	)	$	7,458
Inventory financing arrangements		—		26,582		—			26,582
Other		96		—		—			96
Total liabilities measured at fair value	$	9,047	$	33,813	$	(8,724	)	$	34,136
	Fair Value Measurements at December 31, 2011
	Quoted Prices in Active Markets for Identical Assets		Significant Other Observable Inputs		Reclassification for Balance Sheet
	(Level 1)		(Level 2)		Presentation			Total
Assets
Cash and cash equivalents	$	174,988	$	—	$	—		$	174,988
Restricted cash		21,820		—		—			21,820
Inventories carried at market		—		112,948		—			112,948
Unrealized gains on derivatives		15,710		6,010		(4,292	)		17,428
Total assets measured at fair value	$	212,518	$	118,958	$	(4,292	)	$	327,184
Liabilities
Unrealized losses on derivatives	$	2,828	$	5,287	$	(2,698	)	$	5,417
Margin deposits		1,594		—		(1,594	)		—
Inventory financing arrangements		—		8,894		—			8,894
Other		71		—		—			71
Total liabilities measured at fair value	$	4,493	$	14,181	$	(4,292	)	$	14,382

The Company believes the fair value of its debt approximates book value, which was $739.7 million and $636.8 million at March 31, 2012 and December 31, 2011, respectively. The Company also believes the fair value of its accounts receivable and accounts payable approximate book value, which were $92.7 million and $96.9 million, respectively, at March 31, 2012 and $106.2 million and $172.3 million, respectively, at December 31, 2011.

Although the Company currently does not have any Level 3 financial measurements, the fair values of the tangible assets and goodwill acquired in previous reporting periods represent Level 3 measurements and were derived using a combination of the income approach, the market approach and the cost approach as considered appropriate for the specific assets being valued.

10

3. SEGMENT INFORMATION

Company management reviews financial and operating performance in the following four separate operating segments: (1) production of ethanol and distillers grains, collectively referred to as ethanol production, (2) corn oil production, (3) grain warehousing and marketing, as well as sales and related services of agronomy and petroleum products, collectively referred to as agribusiness, and (4) marketing and distribution of Company-produced and third-party ethanol, distillers grains and corn oil, collectively referred to as marketing and distribution. Selling, general and administrative expenses, primarily consisting of compensation of corporate employees, professional fees and overhead costs not directly related to a specific operating segment, are reflected in the table below as corporate activities.

During the normal course of business, the Company enters into transactions between segments. Examples of these intersegment transactions include, but are not limited to, the ethanol production segment selling ethanol to the marketing and distribution segment and the agribusiness segment selling grain to the ethanol production segment. These intersegment activities are recorded by each segment at prices approximating market and treated as if they are third-party transactions. Consequently, these transactions impact segment performance. However, revenues and corresponding costs are eliminated in consolidation and do not impact the Company’s consolidated results.

The following are certain financial data for the Company’s operating segments for the periods indicated (in thousands):

	Three Months Ended March 31,
	2012			2011
Revenues:
Ethanol production
Revenues from external customers	$	45,358		$	35,119
Intersegment revenues		412,819			432,684
Total segment revenues		458,177			467,803
Corn oil production
Revenues from external customers		508			1,071
Intersegment revenues		13,011			3,251
Total segment revenues		13,519			4,322
Agribusiness
Revenues from external customers		72,825			63,854
Intersegment revenues		45,402			50,264
Total segment revenues		118,227			114,118
Marketing and distribution
Revenues from external customers		656,704			712,283
Intersegment revenues		67			112
Total segment revenues		656,771			712,395
Revenues including intersegment activity		1,246,694			1,298,638
Intersegment eliminations		(471,299	)		(486,311	)
Revenues as reported	$	775,395		$	812,327

11

	Three Months Ended March 31,
	2012			2011
Gross profit (loss):
Ethanol production	$	(10,035	)	$	23,314
Corn oil production		7,936			2,091
Agribusiness		6,246			6,016
Marketing and distribution		4,186			6,674
Intersegment eliminations		437			(471	)
	$	8,770		$	37,624
Operating income (loss):
Ethanol production	$	(13,880	)	$	19,535
Corn oil production		7,848			2,069
Agribusiness		669			972
Marketing and distribution		510			2,639
Intersegment eliminations		471			(456	)
Corporate activities		(6,709	)		(4,763	)
	$	(11,091	)	$	19,996

The following table sets forth revenues by product line for the periods indicated (in thousands):

	Three Months Ended March 31,
	2012		2011
Revenues:
Ethanol	$	583,535	$	654,484
Corn oil		13,155		4,322
Distillers grains		100,604		87,274
Grain		64,219		55,287
Agronomy products		7,118		7,457
Other		6,764		3,503
	$	775,395	$	812,327

The following are total assets for our operating segments for the periods indicated (in thousands):

	March 31, 2012			December 31, 2011
Total assets:
Ethanol production	$	876,160		$	879,500
Corn oil production		26,916			24,601
Agribusiness		225,925			233,201
Marketing and distribution		189,425			181,466
Corporate assets		105,583			121,429
Intersegement eliminations		(20,323	)		(19,369	)
	$	1,403,686		$	1,420,828

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4. INVENTORIES

Inventories are carried at the lower of cost or market, except grain held for sale, which is valued at market value. During the three months ended March 31, 2012, the Company recorded a $0.8 million lower of cost or market adjustment in cost of goods sold within the ethanol production segment. The components of inventories are as follows (in thousands):

	March 31, 2012		December 31, 2011
Finished goods	$	83,655	$	57,882
Grain held for sale		95,236		112,948
Raw materials		29,810		23,215
Petroleum & agronomy items held for sale		18,860		14,206
Work-in-process		13,447		11,418
Supplies and parts		9,917		9,401
	$	250,925	$	229,070

5. GOODWILL

The Company did not have any changes in the total carrying amount of goodwill during the three months ended March 31, 2012, which was $40.9 million. Goodwill of $30.3 million is attributable to the ethanol production segment and $10.6 million is attributable to the marketing and distribution segment.

6. DERIVATIVE FINANCIAL INSTRUMENTS

At March 31, 2012, the Company’s consolidated balance sheet reflects deferred losses, net of tax, of $0.3 million in accumulated other comprehensive loss. The Company expects all of the deferred losses at March 31, 2012 will be reclassified into income over the next 12 months as a result of hedged transactions that are forecasted to occur. The amount ultimately realized in income, however, will differ as commodity prices change.

Fair Values of Derivative Instruments

The following table provides information about the fair values of our derivative financial instruments and the line items in the consolidated balance sheets in which the fair values are reflected:

	Asset Derivatives’ Fair Value						Liability Derivatives’ Fair Value
Derivative Instruments	March 31,			December 31,			March 31,		December 31,
Consolidated Balance Sheet Location	2012			2011			2012		2011
Derivative financial instruments (1)	$	5,508	(2)	$	19,022	(3)	$	—	$	—
Accrued and other liabilities		—			—			7,271		5,280
Other liabilities		—			—			115		137
Total	$	5,508		$	19,022		$	7,386	$	5,417

(1) Derivative financial instruments as reflected on the balance sheet include a margin deposit asset of $22.8 million and a margin deposit liability of $1.6 million at March 31, 2012 and December 31, 2011, respectively.

(2) Balance at March 31, 2012, includes $0.1 million and $1.2 million of net deferred losses on derivative financial instruments designated as cash flow hedging instruments and fair value hedging instruments, respectively.

(3) Balance at December 31, 2011, includes $12.2 million of net deferred gains on derivative financial instruments designated as cash flow hedging instruments.

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Refer to Note 2 - Fair Value Disclosures, which also contains fair value information related to derivative financial instruments.

Effect of Derivative Instruments on Consolidated Statements of Operations and Consolidated Statements of Stockholders’ Equity and Comprehensive Income

The following tables provide information about the gain or loss recognized in income and other comprehensive income on our derivative financial instruments and the line items in the financial statements in which such gains and losses are reflected:

Gains (Losses) on Derivative Instruments Not Designated in a Hedging Relationship	Three Months Ended March 31,
Consolidated Statements of Operations Location	2012			2011
Revenue	$	(2,885	)	$	615
Cost of goods sold		1,185			(25,240	)
Net decrease recognized in earnings	$	(1,700	)	$	(24,625	)

Locations of Gain (Loss) Due to Ineffectiveness of Cash Flow Hedges	Three Months Ended March  31,
Consolidated Statements of Operations Location	2012			2011
Revenue	$	5		$	(118	)
Cost of goods sold		(64	)		20
Net decrease recognized in earnings	$	(59	)	$	(98	)

Location of Gains (Losses) Reclassified from Accumulated Other Comprehensive Income (Loss) into Net Income (Loss)	Three Months Ended March  31,
Consolidated Statements of Operations Location	2012			2011
Revenue	$	617		$	(4,457	)
Cost of goods sold		(4,698	)		3,544
Net decrease recognized in earnings	$	(4,081	)	$	(913	)

Effective Portion of Cash Flow Hedges Recognized in	Three Months Ended March  31,
Other Comprehensive Income (Loss)	2012		2011
Commodity Contracts	$	68	$	(7,553	)

Locations of Gain (Loss) from Fair Value Hedges of Ethanol Inventory	Three Months Ended March  31,
Consolidated Statements of Operations Location	2012			2011
Revenue (effect of change in inventory value)	$	1,218		$	—
Revenue (effect of fair value hedge)		(1,218	)		—
Ineffectiveness recognized in earnings	$	—		$	—

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There were no gains or losses due to the discontinuance of cash flow hedge treatment during the three months ended March 31, 2012.

The table below summarizes the volumes of open commodity derivative positions as of March 31, 2012 (in thousands):

March 31, 2012
	Exchange Traded			Non-Exchange Traded
Derivative Instruments	Net Long & (Short) (1)			Long (2)		(Short) (2)			Unit of Measure	Commodity
Futures		(17,211	)						Bushels	Corn, Soybeans and Wheat
Futures		14,425	(3)						Bushels	Corn
Futures		(41,531	)						Gallons	Ethanol
Futures		(53,844	)(3)						Gallons	Ethanol
Futures		(8,400	)(4)						Gallons	Ethanol
Options		4,797							Bushels	Corn
Options		1,754							Gallons	Ethanol
Forwards					19,030		(7,817	)	Bushels	Corn, Soybeans, Wheat and Milo
Forwards					144,780		(235,765	)	Gallons	Ethanol
Forwards					16		(125	)	Tons	Distillers Grains

(1) Exchange traded futures and options are presented on a net long and (short) position basis. Options are presented on a delta-adjusted basis.

(2) Non-exchange traded forwards are presented on a gross long and (short) position basis.

(3) Futures used for cash flow hedges.

(4) Futures used for fair value hedges.

Energy trading contracts that do not involve physical delivery are presented net in revenues on the consolidated statements of operations. Revenues and cost of goods sold under such contracts are summarized in the table below for the periods indicated (in thousands):

	Three Months Ended March  31,
	2012		2011
Revenue	$	6,575	$	11,274
Cost of goods sold	$	6,485	$	10,872

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7. DEBT

The principal balances of the components of debt are as follows (in thousands):

	March 31, 2012		December 31, 2011
Green Plains Bluffton:
$70.0 million term loan	$	46,268	$	48,018
$20.0 million revolving term loan		20,000		20,000
$22.0 million revenue bond		18,330		19,120
Green Plains Central City:
$55.0 million term loan		45,312		46,558
$30.5 million revolving term loan		28,645		24,739
$11.0 million revolver		10,094		—
Equipment financing loan		154		170
Green Plains Holdings II:
$34.1 million term loan		—		27,914
$42.6 million revolving term loan		—		35,679
$15.0 million revolver		—		15,000
$26.4 million term loan		26,414		—
$51.1 million revolving term loan		50,680		—
Other		194		194
Green Plains Obion:
$60.0 million term loan		23,270		25,670
$37.4 million revolving term loan		36,200		36,200
Note payable		75		85
Equipment financing loan		407		445
Economic development grant		1,402		1,424
Green Plains Ord:
$25.0 million term loan		20,730		21,300
$13.0 million revolving term loan		12,151		12,151
$5.0 million revolver		3,349		3,349
Green Plains Otter Tail:
$30.3 million term loan		26,259		27,386
$4.7 million revolver		4,675		4,675
$19.2 million note payable		18,915		18,883
Capital lease payable		138		166
Green Plains Shenandoah:
$30.0 million term loan		4,868		6,068
$17.0 million revolving term loan		17,000		17,000
Green Plains Superior:
$23.5 million term loan		19,375		20,750
$10.0 million revolving term loan		10,000		10,000
Equipment financing loan		139		156

Continued on the following page

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Continued from the previous page

	March 31, 2012			December 31, 2011
Green Plains Grain:
$30.0 million term loan		29,333			27,833
$195.0 revolving loan		62,000			27,000
Inventory financing arrangements		26,582			8,894
Equipment financing loans		156			311
Notes payable		2,000			2,000
Green Plains Trade:
$70.0 million revolving loan		53,859			33,705
Corporate:
$90.0 million convertible notes		90,000			90,000
Notes Payable		28,787			1,625
Capital Lease		557			606
Other		1,391			1,692
Total debt		739,709			636,766
Less: current portion of long-term debt		(83,787	)		(73,760	)
Less: short-term notes payable and other		(169,603	)		(69,599	)
Long-term debt	$	486,319		$	493,407

Ethanol Production Segment

• Term Loans

o Scheduled principal payments are as follows:

•      Green Plains Bluffton	$0.6 million per month
•      Green Plains Central City	$0.4 million per month
•      Green Plains Holdings II	$1.5 million per quarter
•      Green Plains Obion	$2.4 million per quarter
•      Green Plains Ord	$0.2 million per month
•      Green Plains Otter Tail	$0.4 million per month
•      Green Plains Shenandoah	$1.2 million per quarter
•      Green Plains Superior	$1.4 million per quarter

o Final maturity dates (at the latest) are as follows:

•      Green Plains Bluffton	November 19, 2013
•      Green Plains Central City	July 1, 2016
•      Green Plains Holdings II	July1, 2016
•      Green Plains Obion	August 20, 2014
•      Green Plains Ord	July 1, 2016
•      Green Plains Otter Tail	September 1, 2018
•      Green Plains Shenandoah	May 20, 2013
•      Green Plains Superior	July 20, 2015

• Revolving Term Loans – The revolving term loans are generally available for advances throughout the life of the commitment, subject, in certain cases, to borrowing base restrictions. Allowable advances under the Green Plains Shenandoah loan agreement are reduced by $2.4 million each six-month period commencing on the first day of the month beginning approximately six months after repayment of the term loan, but in no event later than November 1, 2014. Allowable advances under the Green Plains Superior loan agreement are reduced by $2.5 million each six-month period commencing on the first day of the month beginning approximately six months after repayment of the

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term loan, but in no event later than January 1, 2016. Allowable advances under the Green Plains Obion loan agreement are reduced by $4.7 million on a semi-annual basis commencing on March 1, 2015. Allowable advances under the Green Plains Holdings II loan agreement are reduced by $2.7 million on a semi-annual basis commencing on April 1, 2012. Interest-only payments are due each month on all revolving term loans until the final maturity date for the Green Plains Bluffton, Green Plains Central City, Green Plains Ord, Green Plains Otter Tail, Green Plains Shenandoah, and Green Plains Superior loan agreements.

o Final maturity dates (at the latest) are as follows:

•      Green Plains Bluffton	November 19, 2013
•      Green Plains Central City	July 1, 2016
•      Green Plains Holdings II	October 1, 2018
•      Green Plains Obion	September 1, 2018
•      Green Plains Ord	July 1, 2016
•      Green Plains Otter Tail	March 19, 2013
•      Green Plains Shenandoah	November 1, 2016
•      Green Plains Superior	July 1, 2017

Green Plains Bluffton also received $22.0 million in Subordinate Solid Waste Disposal Facility Revenue Bond funds from the City of Bluffton, Indiana. The revenue bond requires: (1) semi-annual principal and interest payments of approximately $1.5 million through March 1, 2019, and (2) a final principal and interest payment of $3.745 million on September 1, 2019. At March 31, 2012, Green Plains Bluffton had $2.5 million of cash that was restricted as to use for payment towards the current maturity and interest of the revenue bond. Such cash is presented as restricted cash on the consolidated balance sheet.

All of the Company’s ethanol production subsidiaries were in compliance with their debt covenants as of March 31, 2012.

Agribusiness Segment

The Green Plains Grain loans, executed on October 28, 2011, are comprised of a $30.0 million amortizing term loan and a $195.0 million revolving credit facility with various lenders. The term loan and revolving credit facility mature on November 1, 2021 and October 28, 2013, respectively.

The $30.0 million amortizing term loan was disbursed in an initial advance in the amount of $28.0 million on October 31, 2011. The remaining $2.0 million amount was advanced on February 7, 2012. Equal payments of principal sufficient to amortize the loan in full over a 15-year period, plus interest, are due on the first day of every month with the remaining outstanding balance and all accrued interest due on November 1, 2021, the loan maturity date. The loan bears interest at a fixed rate of 6.00% per annum. As security for the loan, the lender received a first priority lien on certain real estate and other property owned by the subsidiaries within the agribusiness segment.

The revolving credit facility includes total revolving credit commitments of $195.0 million and an accordion feature whereby amounts available under the facility may be increased by up to $55.0 million of new lender commitments upon agent approval. As security for the revolving credit facility, the lender received a first priority lien on certain cash, inventory, machinery, accounts receivable and other assets owned by subsidiaries of the agribusiness segment. Advances are subject to interest charges at a rate per annum equal to the LIBOR rate for the outstanding period plus the applicable margin or a rate per annum equal to the base rate plus the applicable margin. The principal balance of each advance shall be due and payable on the respective maturity date but no later than October 28, 2013.

The agribusiness segment was in compliance with its respective debt covenants at March 31, 2012.

Inventory Financing Arrangements

The Company has entered into short-term inventory financing arrangements with a financial institution. At March 31, 2012, 3.0 million bushels of corn and 0.5 million bushels of soybeans had been designated as collateral under these contracts at initial values totaling $24.7 million. The Company has accounted for the agreements as short-term notes, rather than sales, and has elected the fair value option to offset fluctuations in market prices of the inventory. At March 31, 2012, grain inventory and the short-term note payable were valued at $26.6 million and were measured using Level 2 inputs.

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Marketing and Distribution Segment

The Green Plains Trade loan is comprised of a senior secured revolving credit facility. Under the loan agreement, as amended, the lender will loan up to $70.0 million, subject to a borrowing base equal to 85% of eligible receivables. The balance is subject to interest charges of either: (1) Base Rate (lender’s commercial floating rate plus 2.5%); or, (2) LIBOR plus 3.5%. At March 31, 2012, Green Plains Trade had $24.5 million in cash that was restricted as to use for payment towards the loan agreement. Such cash is presented in restricted cash on the consolidated balance sheets. The amended revolving credit facility expires on March 31, 2014. As of March 31, 2012, Green Plains Trade was in compliance with all debt covenants.

Corporate Activities

In November 2010, the Company issued $90.0 million of 5.75% Convertible Senior Notes due 2015, or Notes. The Notes represent senior, unsecured obligations of the Company, with interest payable on May 1 and November 1 of each year. The Notes may be converted into shares of the Company’s common stock and cash in lieu of fractional shares of the common stock based on a conversion rate initially equal to 69.7788 shares of the common stock per $1,000 principal amount of Notes, which is equal to an initial conversion price of $14.33 per share. The conversion rate is subject to adjustment upon the occurrence of specified events. The Company may redeem for cash all, but not less than all, of the Notes at any time on and after November 1, 2013, if the last reported sale price of the Company’s common stock equals or exceeds 140% of the applicable conversion price for a specified time period, at a redemption price equal to 100% of the principal amount of the Notes, plus accrued and unpaid interest.

In conjunction with a March 9, 2012 repurchase of common stock from a subsidiary of NTR plc, the Company signed a one-year promissory note bearing 5% interest per annum in the amount of $27.2 million to a subsidiary of NTR plc, which was previously the largest shareholder of the Company. The $27.2 million note is secured by the shares repurchased and the Company’s interest in Green Plains Shenandoah LLC.

Capitalized Interest

The Company had $38 thousand in capitalized interest during the quarterly period ended March 31, 2012.

Restricted Net Assets

At March 31, 2012, there were approximately $541.5 million of net assets at the Company’s subsidiaries that were not available to be transferred to the parent company in the form of dividends, loans, or advances due to restrictions contained in the credit facilities of these subsidiaries.

Other Information

For further information on the debt obligations of the Company, refer to Note 10, Debt, in the consolidated financial statements included in the Company’s annual report on Form 10-K for the year ended December 31, 2011.

8. STOCK-BASED COMPENSATION

The Company has equity incentive plans which reserve a combined total of 3.5 million shares of common stock for issuance pursuant to their terms. The plans provide for the granting of shares of stock, including options to purchase shares of common stock, stock appreciation rights tied to the value of common stock, non-vested stock and non-vested stock unit awards to eligible employees, non-employee directors and consultants. The Company measures share-based compensation grants at fair value on the grant date, adjusted for estimated forfeitures. The Company records noncash compensation expense related to equity awards in its financial statements over the requisite service period on a straight-line basis. All of the Company’s existing share-based compensation awards have been determined to be equity awards.

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A summary of stock option activity for the three months ended March 31, 2012 is as follows:

	Shares			Weighted- Average Exercise Price		Weighted-Average Remaining Contractual Term (in years)		Aggregate Intrinsic Value (in thousands)
Outstanding at December 31, 2011		1,122,499		$	15.68		3.8	$	1,374
Granted		—			—
Exercised		(16,332	)		8.71				45
Forfeited		—			—
Expired		—			—
Outstanding at March 31, 2012		1,106,167		$	15.78		3.6	$	1,865
Exercisable at March 31, 2012 (1)		1,045,167		$	16.00		3.3	$	1,832

(1) Includes in-the-money options totaling 518,667 shares at a weighted-average exercise price of $7.26.

The Company’s option awards allow employees to exercise options through cash payment to the Company for the shares of common stock or through a simultaneous broker-assisted cashless exercise of a share option, through which the employee authorizes the exercise of an option and the immediate sale of the option shares in the open market. The Company uses newly-issued shares of common stock to satisfy its share-based payment obligations.

The following table summarizes non-vested stock award and deferred stock unit, or DSU, activity for the three months ended March 31, 2012:

	Non-Vested Shares and DSU’s			Weighted- Average Grant-Date Fair Value		Weighted-Average Remaining Vesting Term (in years)
Nonvested at December 31, 2011		486,012		$	11.81
Granted		453,859			11.20
Forfeited		—			—
Vested		(269,070	)		11.93
Nonvested at March 31, 2012		670,801		$	11.35		2.3

Compensation costs expensed for share-based payment plans described above were approximately $2.2 million and $1.7 million during the three months ended March 31, 2012 and 2011, respectively. At March 31, 2012, there were $6.9 million of unrecognized compensation costs from share-based compensation arrangements, which is related to non-vested awards. This compensation is expected to be recognized over a weighted-average period of approximately 2.2 years. The potential tax benefit realizable for the anticipated tax deductions of the exercise of share-based payment arrangements generally would approximate 38% of these expense amounts.

9. EARNINGS PER SHARE

Basic earnings per common shares, or EPS, is calculated by dividing net income available to common stockholders by the weighted average number of common shares outstanding during the period. Diluted EPS is computed by dividing net income on an as-if-converted basis available to common stockholders by the weighted average number of common shares outstanding during the period, adjusted for the dilutive effect of any outstanding dilutive securities. Adjusting net income to net income on an as-if-converted basis and adjusting the weighted average number of common shares outstanding for the effect of any outstanding dilutive securities is antidilutive when a net loss has been realized. The reconciliations of net income to net income on an as-if-converted basis and basic and diluted earnings per share are as follows (in thousands):

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	Three Months Ended
	March 31,
	2012			2011
Net income (loss) attributable to Green Plains	$	(12,692	)	$	7,741
Weighted average shares outstanding - basic		32,238			36,199
Income (loss) attributable to Green Plains stockholders - basic	$	(0.39	)	$	0.21
Net income (loss) attributable to Green Plains	$	(12,692	)	$	7,741
Interest and amortization on convertible debt		—			1,440
Tax effect of interest on convertible debt		—			(518	)
Net income (loss) attributable to Green Plains on an as-if-converted basis	$	(12,692	)	$	8,663
Weighted average shares outstanding - basic		32,238			36,199
Effect of dilutive convertible debt		—			6,280
Effect of dilutive stock-based compensation awards		—			285
Total potential shares outstanding		32,238			42,764
Income (loss) attributable to Green Plains stockholders - diluted	$	(0.39	)	$	0.20

Excluded from the computations of diluted EPS were stock-based compensation awards totaling 0.8 million and 0.7 million shares for the three months ended March 31, 2012 and 2011, respectively, because the exercise prices or the grant-date fair value, as applicable, of the corresponding awards were greater than the average market price of the Company’s common stock during the respective periods. For the three months ended March 31, 2012, 0.3 million shares related to stock-based compensation awards and 6.3 million shares related to convertible debt were also excluded from the computation of diluted EPS as the inclusion of these shares would have been antidilutive. As consideration for the acquisition of the Lakota and Riga ethanol plants in October 2010, the Company issued warrants for 700,000 shares of its stock at a price of $14.00 per share. The warrants are excluded from the computations of diluted EPS as the exercise price is greater than the average market price of the Company’s common stock for the three months ended March 31, 2012.

10. STOCKHOLDERS’ EQUITY

Components of stockholders’ equity are as follows (in thousands):

										Accum.
										Other								Total
					Additional					Comp								Green Plains			Non-			Total
	Common Stock				Paid-in		Retained			Income			Treasury Stock					Stockholders’			Controlling			Stockholders’
	Shares		Amount		Capital		Earnings			(Loss)			Shares		Amount			Equity			Interest			Equity
Balance, December 31, 2011		36,414	$	36	$	440,469	$	95,761		$	(2,953	)		3,500	$	(28,201	)	$	505,112		$	245		$	505,357
Net loss		—		—		—		(12,692	)		—			—		—			(12,692	)		(4	)		(12,696	)
Unrealized gain on derivatives,net of tax effect of $1,516		—		—		—		—			2,633			—		—			2,633			—			2,633
Repurchase of common stock		—		—		—		—			—			3,700		(37,607	)		(37,607	)		—			(37,607	)
Stock-based compensation		360		1		1,170		—			—			—		—			1,171			—			1,171
Stock options exercised		16		—		142		—			—			—		—			142			—			142
Balance, March 31, 2012		36,790	$	37	$	441,781	$	83,069		$	(320	)		7,200	$	(65,808	)	$	458,759		$	241		$	459,000

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On March 9, 2012, the Company repurchased 3.7 million shares of its common stock for $37.2 million. Shares of common stock repurchased by the Company are recorded at cost as treasury stock and result in a reduction of stockholders’ equity in the accompanying consolidated balance sheets. When shares are reissued, the Company will use the weighted average cost method for determining the cost basis. The difference between the cost of the shares and the issuance price will be added or deducted from additional paid-in capital. The Company does not have a share repurchase program and does not intend to retire the repurchased shares.

11. INCOME TAXES

The Company records income tax expense or benefit during interim periods based on its best estimate of the annual effective tax rate. Certain items are given discrete period treatment and, as a result, the tax effects of such items are reported in full in the relevant interim period.

Income taxes for the three months ended March 31, 2012 was a benefit of $8.0 million compared to an expense of $4.4 million for the same period in 2011.The effective tax rate (calculated as the ratio of income tax expense to income before income taxes) was approximately 39% and 37% for the first three months of 2012 and 2011, respectively. The effective tax rate for the three months ended March 31, 2011, reflects the release of a portion of valuation allowances provided against certain of the Company’s deferred tax assets, primarily federal and state net operating losses and tax credits due to anticipated income in future periods.

The Company’s unrecognized tax benefits at March 31, 2012 and December 31, 2011 were $0.1 million. There was no change in the Company’s liabilities related to unrecognized tax benefits during the first three months of 2012.

The 2012 annual effective tax rate can be affected as a result of variances among the estimates and amounts of full-year sources of taxable income (among the various states), the realization of tax credits, adjustments that may arise from the resolution of tax matters under review, variances in the release of valuation allowances and the Company’s assessment of its liability for uncertain tax positions.

12. COMMITMENTS AND CONTINGENCIES

Operating Leases

The Company leases certain facilities and parcels of land under agreements that expire at various dates. For accounting purposes, rent expense is based on a straight-line amortization of the total payments required over the lease term. The Company incurred lease expenses of $4.4 million and $3.7 million during the three months ended March 31, 2012 and 2011, respectively. Aggregate minimum lease payments under these agreements for the remainder of 2012 and in future fiscal years are as follows (in thousands):

Year Ending December 31,	Amount
2012	$	12,424
2013		14,829
2014		8,261
2015		6,589
2016		5,376
Thereafter		2,980
Total	$	50,459

Commodities

As of March 31, 2012, the Company had contracted for future grain deliveries valued at approximately $392.2 million, natural gas deliveries valued at approximately $2.1 million, ethanol product deliveries valued at approximately $21.6 million and distillers grains product deliveries valued at approximately $1.0 million.

Legal

In April 2011, Aventine Renewable Energy, Inc. filed a complaint in the United States Bankruptcy Court for the District of Delaware in connection with its Chapter 11 bankruptcy naming as defendants Green Plains Renewable Energy, Inc., Green Plains Obion LLC, Green Plains Bluffton LLC, Green Plains VBV LLC and Green Plains Trade Group LLC. This action alleged $24.4 million of damages from preferential transfers or, in the alternative, $28.4 million of damages from fraudulent

22

transfers under an ethanol marketing agreement and an unspecified amount of damages for a continuing breach of a termination agreement related to rail cars. In April 2012, the parties mutually agreed to a negotiated settlement whereby the Company agreed to a cash payment and the purchase of 20 million gallons of ethanol from Aventine over a four-month period beginning in May 2012. An after-tax charge of $2.4 million for the settlement was reflected in operations for the three months ended March 31, 2012.

In addition to the above-described proceeding, the Company is currently involved in other litigation that has arisen in the ordinary course of business, but it does not believe that any other pending litigation will have a material adverse effect on its financial position, results of operations or cash flows.

13. RELATED PARTY TRANSACTIONS

Short-Term Note Payable

On March 9, 2012, the Company repurchased 3.7 million shares of its Common Stock from a subsidiary of NTR plc, which was previously the largest shareholder of the Company, for $37.2 million. The Company paid $10.1 million in cash and issued a secured note bearing 5% interest per annum for $27.2 million that is due on March 9, 2013. The $27.2 million note is secured by the shares repurchased and the Company’s interest in Green Plains Shenandoah LLC. At March 31, 2012, $27.2 million was outstanding on the note payable.

Commercial Contracts

Three subsidiaries of the Company have executed separate financing agreements for equipment with AXIS Capital Inc. Gordon F. Glade, President and Chief Executive Officer of AXIS Capital is a member of our Board of Directors. Totals of $0.3 million and $0.5 million were included in debt at March 31, 2012 and December 31, 2011, respectively, under these financing arrangements. Payments, including principal and interest, totaled $0.2 million and $0.2 million during the three months ended March 31, 2012 and 2011, respectively. The highest amount outstanding during the three months ended March 31, 2012 was $0.4 million, and the weighted average interest rate for all financing agreements with AXIS Capital was 6.1%.

The Company has entered into ethanol purchase, sale and throughput agreements with Center Oil Company. Gary R. Parker, President and Chief Executive Officer of Center Oil, is a member of our Board of Directors. During the three months ended March 31, 2012 and 2011, cash receipts from Center Oil totaled $2.2 million and $43.1 million, respectively and cash payments to Center Oil totaled $1.0 million and $1.0 million for the same periods, respectively, on these contracts. In October 2011, the Company also entered into an operating lease agreement with Center Oil in which the Company will pay $42 thousand per month for the lease of 35 railcars. The agreement is effective through September 30, 2013. The Company had no outstanding receivables from Center Oil at March 31, 2012 and $1.0 million included in outstanding receivables from Center Oil at December 31, 2011. The Company had no outstanding payables at March 31, 2012 and $69 thousand in outstanding payables at December 31, 2011 under these purchase and sale agreements.

Aircraft Lease

The Company has entered into an agreement with Hoovestol Inc. for the lease of an aircraft. Wayne B. Hoovestol, President of Hoovestol Inc., is Chairman of our Board of Directors. The Company has agreed to pay $6,667 per month for use of up to 100 hours per year of the aircraft. Any flight time in excess of 100 hours per year will incur additional hourly-based charges. During the three months ended March 31, 2012 and 2011, payments related to this agreement totaled $33 thousand and $20 thousand, respectively. The Company did not have any receivables from or payables to Hoovestol Inc. at March 31, 2012 and December 31, 2011.

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

General

The following discussion and analysis provides information which management believes is relevant to an assessment and understanding of our consolidated financial condition and results of operations. This discussion should be read in conjunction with the consolidated financial statements included herewith and notes to the consolidated financial statements thereto and our annual report filed on Form 10-K for the year ended December 31, 2011 including the consolidated financial statements, accompanying notes and the risk factors contained therein.

Cautionary Information Regarding Forward-Looking Statements

This report contains forward-looking statements based on current expectations that involve a number of risks and uncertainties. Forward-looking statements generally do not relate strictly to historical or current facts, but rather to plans and objectives for future operations based upon management’s reasonable estimates of future results or trends, and include statements preceded by, followed by, or that include words such as “anticipates,” “believes,” “continue,” “estimates,” “expects,” “intends,” “outlook,” “plans,” “predicts,” “may,” “could,” “should,” “will,” and words and phrases of similar impact, and include, but are not limited to, statements regarding future operating or financial performance, business strategy, business environment, key trends, and benefits of actual or planned acquisitions. In addition, any statements that refer to expectations, projections or other characterizations of future events or circumstances, including any underlying assumptions, are forward-looking statements. The forward-looking statements are made pursuant to safe harbor provisions of the Private Securities Litigation Reform Act of 1995. Although we believe that our expectations regarding future events are based on reasonable assumptions, any or all forward-looking statements in this report may turn out to be incorrect. They may be based on inaccurate assumptions or may not account for known or unknown risks and uncertainties. Consequently, no forward-looking statement is guaranteed, and actual future results may vary materially from the results expressed or implied in our forward-looking statements. The cautionary statements in this report expressly qualify all of our forward-looking statements. In addition, we are not obligated, and do not intend, to update any of our forward-looking statements at any time unless an update is required by applicable securities laws. Factors that could cause actual results to differ from those expressed or implied in the forward-looking statements include, but are not limited to, those discussed in Part I, Item 1A – Risk Factors of our annual report on Form 10-K for the year ended December 31, 2011 and in Item 1A of Part II of this Quarterly Report for the quarter ended March 31, 2012. Specifically, we may experience significant fluctuations in future operating results due to a number of economic conditions, including, but not limited to, competition in the ethanol and other industries in which we compete, commodity market risks, financial market risks, counter-party risks, risks associated with changes to federal policy or regulation, expected corn oil recovery rates and operating expenses, risks related to closing and achieving anticipated results from acquisitions, and other risk factors detailed in our reports filed with the SEC. Actual results may differ from projected results due, but not limited, to unforeseen developments.

In light of these assumptions, risks and uncertainties, the results and events discussed in the forward-looking statements contained in this report or in any document incorporated by reference might not occur. Investors are cautioned not to place undue reliance on the forward-looking statements, which speak only as of the date of this report or the date of the document incorporated by reference in this report. We are not under any obligation, and we expressly disclaim any obligation, to update or alter any forward-looking statements, whether as a result of new information, future events or otherwise.

Overview

We are a leading, vertically-integrated producer, marketer and distributer of ethanol. We focus on generating stable operating margins through our diversified business segments and our risk management strategy. We believe that owning and operating assets throughout the ethanol value chain enables us to mitigate changes in commodity prices and differentiates us from companies focused only on ethanol production. Today, we have operations throughout the ethanol value chain, beginning upstream with our agronomy and grain handling operations, continuing through our approximately 740 million gallons per year, or mmgy, of ethanol production capacity and ending downstream with our ethanol marketing, distribution and blending facilities.

Management reviews our operations in the following four separate operating segments:

• Ethanol Production. We operate a total of nine ethanol plants in Indiana, Iowa, Michigan, Minnesota, Nebraska and Tennessee, with approximately 740 mmgy of total ethanol production capacity. At capacity, these plants collectively will consume approximately 265 million bushels of corn and produce approximately 2.1 million tons of distillers grains annually.

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• Corn Oil Production. We operate corn oil extraction systems at all nine of our ethanol plants, with the capacity to produce approximately 130 million pounds annually. The corn oil systems are designed to extract non-edible corn oil from the whole stillage process immediately prior to production of distillers grains. Industrial uses for corn oil include feedstock for biodiesel, livestock feed additives, rubber substitutes, rust preventatives, inks, textiles, soaps and insecticides.

• Agribusiness. We operate three lines of business within our agribusiness segment: bulk grain, agronomy and petroleum. In our bulk grain business, we have 15 grain elevators with approximately 39.1 million bushels of total storage capacity. We sell fertilizer and other agricultural inputs and provide application services to area producers, through our agronomy business. Additionally, we sell petroleum products including diesel, soydiesel, blended gasoline and propane, primarily to agricultural producers and consumers. We believe our bulk grain business provides synergies with our ethanol production segment as it supplies a portion of the feedstock for our ethanol plants.

• Marketing and Distribution. Our in-house marketing business is responsible for the sales, marketing and distribution of all ethanol, distillers grains and corn oil produced at our nine ethanol plants. We also market and distribute ethanol for third-party ethanol producers with production capacity totaling approximately 260 mmgy. Additionally, our wholly-owned subsidiary, BlendStar LLC, operates nine blending or terminaling facilities with approximately 625 mmgy of total throughput capacity in seven states in the south central United States.

We intend to continue to take a disciplined approach in evaluating new opportunities related to potential acquisition of additional ethanol plants by considering whether the plants fit within the design, engineering and geographic criteria we have developed. In our marketing and distribution segment, our strategy is to renew existing marketing contracts, as well as enter new contracts with other ethanol producers. We also intend to pursue opportunities to develop or acquire additional grain elevators and agronomy businesses, specifically those located near our ethanol plants. We believe that owning additional agribusiness operations in close proximity to our ethanol plants enables us to strengthen relationships with local corn producers, allowing us to source corn more effectively and at a lower average cost. We also plan to continue to grow our downstream access to customers and are actively seeking new marketing opportunities with other ethanol producers.

We continue our support of the BioProcess Algae joint venture, which is focused on developing technology to grow and harvest algae, which consume carbon dioxide, in commercially viable quantities. Construction of Phase II was completed and the Grower Harvesters™ bioreactors were successfully started up in January 2011. Phase II allows for verification of growth rates, energy balances and operating expenses, which are considered to be some of the key steps to commercialization. The cost of the Phase II project was shared by the joint venture partners. As part of the Phase II funding, we increased our ownership in BioProcess Algae to 35%. Effective April 23, 2012, our ownership of BioProcess Algae increased to 49% pursuant to our purchase of ownership interests previously held by NTR plc. During the third quarter of 2011, BioProcess Algae constructed an outdoor Grower Harvester system next to our Shenandoah ethanol plant, which is successfully producing algae. BioProcess Algae successfully completed its first round of algae-based poultry feed trials, in conjunction with the University of Illinois. The algae strains produced by the Grower Harvester system for the feed trials demonstrated high energy and protein content that was readily available, similar to other high value feed products used in the feeding of poultry today. BioProcess Algae broke ground on a five acre algae farm in the first quarter of 2012 at the same location. If we and the other BioProcess Algae members determine that the venture can achieve the desired economic performance from the five acre farm, a build-out of 400 acres of Grower Harvester reactors will be considered. The cost of such a build-out is estimated at $40 million to $60 million and could take up to a year to complete. Funding for BioProcess Algae for such a project would come from a variety of sources including current partners, new equity investors, debt financing or a combination thereof. If a decision was made to replicate such a 400 acre algae farm at all of our ethanol plants, we estimate that the required investment could range from $300 million to $500 million. BioProcess Algae currently is exploring potential algae markets including animal feeds, nutraceuticals and biofuels.

Industry Factors Affecting our Results of Operations

Variability of Commodity Prices. Our operations and our industry are highly dependent on commodity prices, especially prices for corn, ethanol, distillers grains and natural gas. Because the market prices of these commodities are not always correlated, at times ethanol production may be unprofitable. As commodity price volatility poses a significant threat to our margin structure, we have developed a risk management strategy focused on locking in favorable operating margins when available. We continually monitor market prices of corn, natural gas and other input costs relative to the prices for ethanol and distillers grains at each of our production facilities. We create offsetting positions by using a combination of derivative instruments, fixed-price purchases and sales contracts, or a combination of strategies within strict limits. Our primary focus is not to manage general price movements of individual commodities, for example to minimize the cost of corn consumed, but rather to lock in favorable profit margins whenever possible. By using a variety of risk management tools and hedging strategies, including our internally-developed real-time margin management system, we believe we are able to maintain a disciplined approach to price risks.

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The ethanol industry increased production in the fourth quarter of 2011 to meet demand from ethanol blenders in order to take advantage of the Volumetric Ethanol Excise Tax Credit, or VEETC, prior to its expiration on December 31, 2011. As a result, ethanol stocks at the end of 2011 exceeded normal market levels which have caused ethanol margins to compress to near break-even levels since the end of 2011. According to the Energy Information Administration, as an industry, ethanol producers have responded by reducing production by approximately 10% compared to the fourth quarter of 2011. We believe that U.S. ethanol production levels will continue to adjust with marginally efficient plants reducing output until supply and demand return to equilibrium. Further, we believe that the price of corn may be affected by reduced ethanol production levels, although weather, world-wide demand, and other market forces may impact corn prices as well. These factors, in combination with reduced demand for motor fuels in the U.S. resulting from higher gasoline prices and more fuel-efficient vehicles, have adversely affected the margin environment in the first quarter of 2012. The margin environment in the second quarter of 2012, although improving, is also affected by these factors.

There may be periods of time that, due to the variability of commodity prices and compressed margins identified by our risk management system, we reduce or cease ethanol production operations at certain of our ethanol plants. In the first quarter of 2012, we reduced production volumes at two of our ethanol plants by approximately 30%, or about 5% of our total production, in direct response to unfavorable operating margins. Additionally, we started building ethanol inventory levels during the first quarter of 2012 to hold for sale while the market provided a reasonable return on storage capacity. To optimize the value of our assets, we began utilizing a portion of our railcar fleet in the first quarter of 2012 to transport crude oil for third parties from North Dakota to various markets. We plan to continue to pursue this strategy in the second quarter.

Reduced Availability of Capital. Some ethanol producers have faced financial distress over the past few years, culminating with bankruptcy filings by several companies. This, in combination with continued volatility in the capital markets, has resulted in reduced availability of capital for the ethanol industry in general. In this market environment, we may experience limited access to incremental financing.

Legislation. Federal and state governments have enacted numerous policies, incentives and subsidies to encourage the usage of domestically-produced alternative fuel solutions. Passed in 2007 as part of the Energy Independence and Security Act, a federal Renewable Fuels Standard, or RFS, has been and we expect will continue to be a driving factor in the growth of ethanol usage. The RFS Flexibility Act was introduced on October 5, 2011 in the U.S. House of Representatives to reduce or eliminate the volumes of renewable fuel use required by RFS based upon corn stocks-to-use ratios. The Domestic Alternative Fuels Act of 2012 was introduced on January 18, 2012 in the U.S. House of Representatives to modify the RFS to include ethanol and other fuels produced from fossil fuels like coal and natural gas.

To further drive growth in the increased adoption of ethanol, Growth Energy, an ethanol industry trade association, and a number of ethanol producers requested a waiver from the EPA to increase the allowable amount of ethanol blended into gasoline from the current 10% level, or E10, to a 15% level, or E15. In October 2010, the EPA granted a partial waiver for E15 for use in model year 2007 and newer model passenger vehicles, including cars, SUVs, and light pickup truck. In January 2011, the EPA granted a second partial waiver for E15 for use in model year 2001 to 2006 passenger vehicles. On February 17, 2012, the EPA announced that evaluation of the health effects tests of E15 are complete and that fuel manufacturers are now able to register E15 with the EPA to sell. One of the final requirements by the EPA prior to introducing E15 into the marketplace was a survey to verify that E15 met federal fueling specifications. In April 2012, a group of ethanol industry members funded a national survey to meet the EPA’s requirement for a fuel survey on E15. As of April 9, 2012, 26 fuel manufacturers were registered to sell E15.

On July 21, 2010, President Obama signed the Dodd-Frank Wall Street Reform and Consumer Protection Act, or the Reform Act, which, among other things, aims to improve transparency and accountability in derivative markets. While the Reform Act increases the regulatory authority of the Commodity Futures Trading Commission, or CFTC, regarding over-the-counter derivatives, there is uncertainty on several issues related to market clearing, definitions of market participants, reporting, and capital requirements. While many details remain to be addressed in CFTC rulemaking proceedings, at this time we do not anticipate any material impact to our risk management strategy.

Industry Fundamentals. The ethanol industry is supported by a number of market fundamentals that drive its long-term outlook and extend beyond the short-term margin environment. Following the EPA’s completion of health effects testing, the industry is working to broadly introduce E15 into the retail fuel market. Another driving factor is the RFS mandate, which continues to increase each year through 2015. The mandate increased to 13.2 billion gallons for 2012, 600 million gallons

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over the mandated volume in 2011. The makeup of the domestic gasoline market continues to evolve as refiners are producing more CBOB, a sub-grade (84 octane) gasoline, which requires ethanol or other octane sources to meet the minimum octane rating requirements for the U.S. gasoline market. In addition, ethanol export markets are expected to remain active in 2012. Overall, the industry is operating at the mandated levels and ethanol prices have continued to remain at a large discount to gasoline, providing blenders and refiners with a strong economic incentive to blend.

Critical Accounting Policies and Estimates

This disclosure is based upon our consolidated financial statements, which have been prepared in accordance with accounting principles generally accepted in the United States. The preparation of these financial statements requires that we make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues and expenses, and related disclosure of contingent assets and liabilities. We base our estimates on historical experience and other assumptions that we believe are proper and reasonable under the circumstances. We continually evaluate the appropriateness of estimates and assumptions used in the preparation of our consolidated financial statements. Actual results could differ materially from those estimates. Key accounting policies, including but not limited to those relating to revenue recognition, property and equipment, impairment of long-lived assets and goodwill, derivative financial instruments, and accounting for income taxes, are impacted significantly by judgments, assumptions and estimates used in the preparation of the consolidated financial statements. See further discussion of our critical accounting policies and estimates, as well as significant accounting policies, in our annual report on Form 10-K for the year ended December 31, 2011.

Recent Accounting Pronouncements

Effective January 1, 2012, we adopted the third phase of amended guidance in ASC Topic 820, Fair Value Measurements and Disclosures. The amended guidance clarifies the application of existing fair value measurement 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. We currently are not impacted by the additional disclosure requirements as we do not have any recurring Level 3 measurements.

Effective January 1, 2012, we adopted the amended guidance in ASC Topic 220, Comprehensive Income. The amended guidance is aimed at increasing the prominence of other comprehensive income in the financial statements by eliminating the option to present other comprehensive income in the statement of stockholders’ equity. We elected to present net income and other comprehensive income in two separate but consecutive statements. The updated presentation, which has been implemented retroactively for all comparable periods presented, did not impact our financial position or results of operations.

Effective January 1, 2012, we adopted the amended guidance in ASC Topic 350, Intangibles – Goodwill and Other. The amended guidance permits an entity to first assess qualitative factors to determine whether it is more likely than not that the fair value of a reporting unit is less than its carrying amount as a basis for determining whether it is necessary to perform the two-step goodwill impairment test. The more-likely-than-not threshold is defined as having a likelihood of more than 50 percent. We have determined that the amended guidance does not impact our disclosure or reporting requirements.

Off-Balance Sheet Arrangements

We do not have any off-balance sheet arrangements that have or are reasonably likely to have a current or future material effect on our consolidated financial condition, results of operations or liquidity.

Components of Revenues and Expenses

Revenues. In our ethanol production segment, our revenues are derived primarily from the sale of ethanol and distillers grains, which is a co-product of the ethanol production process. In our corn oil production segment, our revenues are derived from the sale of corn oil, which is extracted from the whole stillage process immediately prior to the production of distillers grains. In our agribusiness segment, the sale of grain, fertilizer and petroleum products are our primary sources of revenue. In our marketing and distribution segment, the sale of ethanol, distillers grains and corn oil that we market for our nine ethanol plants and the sale of ethanol we market for the ethanol plants owned by third parties represent our primary sources of revenue. Revenues also include net gains or losses from derivatives.

Cost of Goods Sold. Cost of goods sold in our ethanol production and corn oil production segments includes costs for direct labor, materials and certain plant overhead costs. Direct labor includes all compensation and related benefits of non-management personnel involved in the operation of our ethanol plants. Plant overhead costs primarily consist of plant utilities, plant depreciation and outbound freight charges. Our cost of goods sold is mainly affected by the cost of ethanol, corn, natural gas and transportation. In these segments, corn is our most significant raw material cost. We purchase natural gas to power steam generation in our ethanol production process and to dry our distillers grains. Natural gas represents our second largest cost in this business segment. Cost of goods sold also includes net gains or losses from derivatives.

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Grain, fertilizer and petroleum acquisition costs represent the primary components of cost of goods sold in our agribusiness segment. Grain inventories, forward purchase contracts and forward sale contracts are valued at market prices, where available, or other market quotes adjusted for differences, primarily transportation, between the exchange-traded market and the local markets on which the terms of the contracts are based. Changes in the market value of grain inventories, forward purchase and sale contracts, and exchange-traded futures and options contracts are recognized in earnings as a component of cost of goods sold.

In our marketing and distribution segment, purchases of ethanol, distillers grains and corn oil represent the largest components of cost of goods sold. Transportation expense represents an additional major component of our cost of goods sold in this segment. Transportation expense includes rail car leases, freight and shipping of our ethanol and co-products, as well as costs incurred in storing ethanol at destination terminals.

Selling, General and Administrative Expenses. Selling, general and administrative expenses are recognized at the operating segment level, as well as at the corporate level. These expenses consist of employee salaries, incentives and benefits; office expenses; board fees; and professional fees for accounting, legal, consulting, and investor relations activities. Personnel costs, which include employee salaries, incentives and benefits, are the largest single category of expenditures in selling, general and administrative expenses. We refer to selling, general and administrative expenses that are not allocable to a segment as corporate activities.

Other Income (Expense). Other income (expense) includes interest earned, interest expense and other non-operating items.

Results of Operations

Segment Results

Our operations fall within the following four segments: (1) production of ethanol and related distillers grains, collectively referred to as ethanol production, (2) corn oil production, (3) grain warehousing and marketing, as well as sales and related services of agronomy and petroleum products, collectively referred to as agribusiness, and (4) marketing and distribution of Company-produced and third-party ethanol, distillers grains and corn oil, collectively referred to as marketing and distribution. Selling, general and administrative expenses, primarily consisting of compensation of corporate employees, professional fees and overhead costs not directly related to a specific operating segment, are reflected in the table below as corporate activities. When the Company’s management evaluates segment performance, they review the information provided below, as well as segment earnings before interest, income taxes, noncontrolling interest, depreciation and amortization.

During the normal course of business, our operating segments enter into transactions with one another. For example, our ethanol production and corn oil production segments sell ethanol, distillers grains and corn oil to our marketing and distribution segment and our agribusiness segment sells grain to our ethanol production segment. These intersegment activities are recorded by each segment at prices approximating market and treated as if they are third-party transactions. Consequently, these transactions impact segment performance. However, intersegment revenues and corresponding costs are eliminated in consolidation, and do not impact our consolidated results.

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The table below reflects selected operating segment financial information for the periods indicated (in thousands):

	Three Months Ended March 31,
	2012			2011
Revenues:
Ethanol production
Revenues from external customers	$	45,358		$	35,119
Intersegment revenues		412,819			432,684
Total segment revenues		458,177			467,803
Corn oil production
Revenues from external customers		508			1,071
Intersegment revenues		13,011			3,251
Total segment revenues		13,519			4,322
Agribusiness
Revenues from external customers		72,825			63,854
Intersegment revenues		45,402			50,264
Total segment revenues		118,227			114,118
Marketing and distribution
Revenues from external customers		656,704			712,283
Intersegment revenues		67			112
Total segment revenues		656,771			712,395
Revenues including intersegment activity		1,246,694			1,298,638
Intersegment eliminations		(471,299	)		(486,311	)
Revenues as reported	$	775,395		$	812,327
Gross profit (loss):
Ethanol production	$	(10,035	)	$	23,314
Corn oil production		7,936			2,091
Agribusiness		6,246			6,016
Marketing and distribution		4,186			6,674
Intersegment eliminations		437			(471	)
	$	8,770		$	37,624
Operating income (loss):
Ethanol production	$	(13,880	)	$	19,535
Corn oil production		7,848			2,069
Agribusiness		669			972
Marketing and distribution		510			2,639
Intersegment eliminations		471			(456	)
Corporate activities		(6,709	)		(4,763	)
	$	(11,091	)	$	19,996

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Three Months Ended March 31, 2012 Compared to the Three Months Ended March 31, 2011

Consolidated Results

Revenues decreased $36.9 million for the three months ended March 31, 2012 compared to the same period in 2011 as a result of a reduction in ethanol volumes sold at certain of our ethanol plants, a decrease in activity within our marketing and distribution segment and unfavorable changes in commodity prices. In the first quarter of 2012, we made a decision, in direct response to unfavorable operating margins, to reduce ethanol production volumes at two of our ethanol plants by approximately 30% or about 5% of our total production. In addition, we increased our ethanol inventory levels during the first quarter of 2012 to hold ethanol for sale while the market provided a reasonable return on storage capacity. The decrease in revenues was offset partially by additional production from our Otter Tail ethanol plant, acquired in March 2011, and an increase in corn oil production. During the three months ended March 31, 2012, we were extracting corn oil at all nine of our ethanol plants compared to six of our ethanol plants during the three months ended March 31, 2011, two of which were deployed during that period. Gross profit decreased $28.9 million for the three months ended March 31, 2012 compared to the same period in 2011 primarily as a result of unfavorable operating margins within the ethanol production segment. Operating income decreased $31.1 million in the first quarter of 2012 to an operating loss compared to the first quarter of 2011 as a result of the factors discussed above. Selling, general and administrative expenses were $2.2 million higher for the three months ended March 31, 2012 compared to the same period in 2011 due to the expanded scope of our operations. Interest expense increased by $0.9 million in the first three months of 2012 compared to the same period in 2011 due to debt issued to finance the acquisition of our Otter Tail ethanol plant in March 2011 and higher balances on grain company term loans. As a result of our net loss, we recorded an income tax benefit of $8.0 million compared to an income tax expense of $4.4 million for three months ended March 31, 2012 and 2011, respectively.

The following discussion of segment results provides greater detail on period to period results.

Ethanol Production Segment

The table below presents key operating data within our ethanol production segment for the periods indicated:

	Three Months Ended March 31,
	2012		2011
Ethanol sold
(thousands of gallons)		169,620		172,093
Ethanol produced
(thousands of gallons)		175,771		171,104
Distillers grains sold
(thousands of equivalent dried tons)		487		505
Corn consumed
(thousands of bushels)		61,873		60,371

Revenues in the ethanol production segment decreased by $9.6 million for the three months ended March 31, 2012 compared to the same period in 2011. The decrease in revenue was due to the decision, in direct response to unfavorable operating margins, to temporarily reduce ethanol production volumes at two of our ethanol plants by approximately 30% or about 5% of our total production and lower average prices for ethanol during the quarter compared to the same period in 2011. Our expected operating capacity per quarter is 185 million gallons of ethanol. However, the ethanol production segment produced 176 million and sold 170 million gallons of ethanol during the first quarter of 2012. We started building ethanol inventory levels during the first quarter of 2012 to hold for sale. Revenues for the three months ended March 31, 2012, included production from our Otter Tail ethanol plant, which was acquired in March 2011. The Otter Tail plant contributed an additional $25.2 million in revenues for the three months ended March 31, 2012 compared to the same period in 2011.

Cost of goods sold in the ethanol production segment increased by $23.7 million for the three months ended March 31, 2012 compared to the same period in 2011. The increase was due primarily to the additional consumption of 1.5 million bushels of corn and a 4.5% increase in the average cost per bushel during the three months ended March 31, 2012 compared to the same period in 2011. Cost of goods sold also included a one-time charge related to the settlement of a legal claim. Gross profit for the ethanol production segment decreased by $33.3 million for the three months ended March 31, 2012 compared to the same period in 2011 due to the factors listed above.

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Operating income in the ethanol production segment decreased by $33.4 million for the three months ended March 31, 2012, compared to the same period in 2011, to a loss of $10.0 million, due in large part to the factors discussed above. Depreciation and amortization expense for the ethanol production segment was $11.0 million during the three months ended March 31, 2012 compared to $10.7 million during the same period in 2011.

Corn Oil Production Segment

Revenues in the corn oil production segment increased by $9.2 million for the three months ended March 31, 2012 compared to the same period in the prior year. During the three months ended March 31, 2012, we sold 33.5 million pounds of corn oil compared to 10.1 million pounds in the same period of 2011. We began extracting corn oil in the fourth quarter of 2010 and had deployed corn oil extraction technology at four of our ethanol plants by December 31, 2010. In 2011, we began extracting corn oil at our other five ethanol plants with the last implementation at our Otter Tail plant completed during the third quarter of 2011. As of March 31, 2011, we had deployed corn oil extraction technology at six of our ethanol plants.

Gross profit and operating income in the corn oil production segment increased by $5.8 million for the three months ended March 31, 2012 compared to the same period in 2011. The increase is primarily attributable to the increase in production volumes discussed above.

Agribusiness Segment

The table below presents key operating data within our agribusiness segment for the periods indicated:

	Three Months Ended March  31,
	2012		2011
Grain sold
(thousands of bushels)		14,385		13,954
Fertilizer sold
(tons)		2,357		3,108

Our agribusiness segment had an increase of $4.1 million in revenues, an increase of $0.2 million in gross profit, and a decrease in operating income of $0.3 million for the three months ended March 31, 2012 compared to the same period in 2011. Revenues and gross profit increased primarily due to additional volume of grain sold and higher unit margins for grain and fertilizer. The decrease in operating income was affected by an increase in selling, general and administrative expenses due to the expanded scope of our agribusiness operations, through construction of grain storage capacity and the acquisition of two grain elevators in June 2011 and January 2012, respectively. The agribusiness segment’s quarterly performance fluctuates on a seasonal basis with generally stronger results expected in the second and fourth quarters each year.

Marketing and Distribution Segment

Revenues in our marketing and distribution segment decreased by $55.6 million for the three months ended March 31, 2012 compared to the same period in 2011. The decrease in revenues was primarily due to a decrease in quantities of ethanol sold and lower average prices. Ethanol revenues, including revenues from third party marketing agreements, decreased by $74.9 million partially offset by an increase in distillers grains and corn oil revenues of $8.3 million and $9.8 million, respectively. During the quarter ended March 31, 2012, we sold 33.5 million pounds of corn oil. We sold 251.4 million gallons of ethanol within the marketing and distribution segment during the quarter ended March 31, 2012 compared to 277.5 million gallons sold during the same period in 2011. Ethanol volumes decreased due to a decrease in volumes marketed under third-party marketing agreements and from our ethanol production segment. Marketing and distribution for third-party ethanol producers decreased by 46.8 million gallons for the three months ended March 31, 2012 compared to the same period in 2011.

Gross profit and operating income for the marketing and distribution segment decreased $2.5 million and $2.1 million, respectively, for the three months ended March 31, 2012 compared to the same period in 2011. The decreases in gross profit and operating income were due primarily to lower profits realized from ethanol and distillers grains trading positions.

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Intersegment Eliminations

Intersegment eliminations of revenues decreased $15.0 million for the three months ended March 31, 2012 compared to the same period in 2011 due to a decrease of $26.7 million in ethanol and increases of $6.8 million and $9.8 million in distillers grains and corn oil, respectively, sold from our ethanol production and corn oil segments to our marketing and distribution segment. In addition, corn sales from our agribusiness segment decreased $4.9 million between the periods.

Corporate Activities

Operating income was impacted by an increase in operating expenses for corporate activities of $1.9 million for the three months ended March 31, 2012 compared to the same period in 2011, primarily due to an increase in general and administrative expenses and personnel costs related to expanded operations.

Income Taxes

We record an income tax expense or benefit during interim periods based on our best estimate of the annual effective tax rate. We recorded an income tax benefit of $8.0 million for the three months ended March 31, 2012 compared to an income tax expense of $4.4 million for the same period in 2011. The effective tax rate (calculated as the ratio of income tax expense to income before income taxes) was approximately 39% and 36% for the first quarters of 2012 and 2011, respectively. The effective tax rate for the first quarter of 2011 reflects the release of a portion of valuation allowances provided against certain of our deferred tax assets, primarily federal and state net operating losses and tax credits.

EBITDA

Management uses earnings before interest, income taxes, noncontrolling interests, depreciation and amortization, or EBITDA, to measure our financial performance and to internally manage our businesses. Management believes that EBITDA provides useful information to investors as a measure of comparison with peer and other companies. EBITDA should not be considered an alternative to, or more meaningful than, net income or cash flow as determined in accordance with generally accepted accounting principles. EBITDA calculations may vary from company to company. Accordingly, our computation of EBITDA may not be comparable with a similarly titled measure of another company. The following sets forth the reconciliation of net income (loss) to EBITDA for the periods indicated (in thousands):

	Three Months Ended March 31,
	2012			2011
Net income (loss) attributable to Green Plains	$	(12,692	)	$	7,741
Net loss attributable to noncontrolling interests		(4	)		(210	)
Interest expense		9,067			8,132
Income taxes		(8,001	)		4,361
Depreciation and amortization		13,158			12,003
EBITDA	$	1,528		$	32,027

Liquidity and Capital Resources

On March 31, 2012, we had $135.0 million in cash and equivalents, comprised of $44.4 million held at our parent company and the remainder at our subsidiaries. We also had up to an additional $152.4 million available under revolving credit agreements at our subsidiaries, some of which was subject to borrowing base restrictions or other specified lending conditions at March 31, 2012. Funds held at our subsidiaries are generally required for their ongoing operational needs and distributions from our subsidiaries are restricted pursuant to these loan agreements. At March 31, 2012, there were approximately $541.5 million of net assets at our subsidiaries that were not available to be transferred to the parent company in the form of dividends, loans or advances due to restrictions contained in the credit facilities of these subsidiaries.

We incurred capital expenditures of $5.7 million in the first three months of 2012 primarily for the construction of a new unit train terminal in Birmingham, Alabama. Capital spending for the remainder of 2012 is expected to be approximately $25.6 million primarily for the construction of the unit train terminal, expected to be operational by the fourth quarter of 2012. The remainder of our capital spending primarily relates to other recurring capital expenditures in the ordinary course of business. We believe available borrowings under our credit facilities and cash provided by operating activities will be sufficient to support our working capital, capital expenditures and debt service requirements for the foreseeable future.

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We have entered into short-term inventory financing arrangements with a financial institution. At March 31, 2012, 3.0 million bushels of corn and 0.5 million bushels of soybeans had been designated as collateral under these contracts at initial values totaling $24.7 million. We have accounted for the agreements as short-term notes, rather than sales, and have elected the fair value option to offset fluctuations in market prices of the inventory. At March 31, 2012, grain inventories and the short-term note payable were valued at $26.6 million.

Net cash used by operating activities was $92.9 million for the three months ended March 31, 2012 compared to $91.2 million for the same period in 2011. Cash used by operating activities for the three months ended March 31, 2012 and 2011 included significant cash outflows for deferred grain contract payables within our agribusiness segment. Additional factors affecting the net cash used by operating activities during the three months ended March 31, 2012 included a net loss of $12.7 million and cash outflows related to the increase in inventories with partially offsetting cash inflows related to the reduction in accounts receivable. Net cash used by investing activities was $7.2 million for the three months ended March 31, 2012, due the construction of a new unit train terminal. Net cash provided by financing activities was $60.0 million for the three months ended March 31, 2012 due to an increase in short-term notes payable, used to finance grain contract settlements and inventory purchases, partially offset by $10.4 million in cash outflows for the repurchase of treasury stock and scheduled principal repayments of long-term debt in the first quarter of 2012. Green Plains Trade and Green Plains Grain utilize revolving credit facilities to finance working capital requirements. These facilities are frequently drawn upon and repaid resulting in significant cash movements that are reflected on a gross basis within financing activities as proceeds from and payments on short-term borrowings. We made scheduled principal payments of $13.1 million in debt reduction on our term debt facilities and long-term revolving credit facilities, offset by advances of $16.0 million from long-term revolving credit facilities, during the three months ended March 31, 2012.

Our business is highly impacted by commodity prices, including prices for corn, ethanol, distillers grains and natural gas. We attempt to reduce the market risk associated with fluctuations in commodity prices through the use of derivative financial instruments. Sudden changes in commodity prices may require cash deposits with brokers, or margin calls. Depending on our open derivative positions, we may require significant liquidity with little advanced notice to meet margin calls. We continuously monitor our exposure to margin calls and believe that we will continue to maintain adequate liquidity to cover such margin calls from operating results and borrowings. Recent increases in grain prices and our expanded grain handling capacity have led to more frequent and larger margin calls.

We were in compliance with our debt covenants at March 31, 2012. Based upon our current forecasts, we believe we will maintain compliance at each of our subsidiaries for the upcoming twelve months, or if necessary have sufficient liquidity available on a consolidated basis to resolve a subsidiary’s noncompliance; however, no obligation exists to provide such liquidity for a subsidiary’s compliance. No assurance can be provided that actual operating results will approximate our forecasts or that we will inject the necessary capital into a subsidiary to maintain compliance with its respective covenants. In the event actual results differ significantly from our forecasts and a subsidiary is unable to comply with its respective debt covenants, the subsidiary’s lenders may determine that an event of default has occurred. Upon the occurrence of an event of default, and following notice, the lenders may terminate any commitment and declare the entire unpaid balance due and payable.

We believe that we have sufficient working capital for our existing operations. However, we can provide no assurance that we will be able to secure additional funding for our future operations. A sustained period of unprofitable operations may strain our liquidity and make it difficult to maintain compliance with our financing arrangements. While we may seek additional sources of working capital in response, we can provide no assurance that we will be able to secure this funding if necessary. We may sell additional equity or borrow additional amounts to improve or preserve our liquidity; expand our ethanol plants; build additional or acquire existing ethanol plants; or build additional or acquire existing agribusiness and ethanol distribution facilities. We can provide no assurance that we will be able to secure the funding necessary for these additional projects or for additional working capital needs at reasonable terms, if at all.

Debt

For additional information related to our debt, see Note 7 – Debt included herein as part of the Notes to Consolidated Financial Statements.

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Ethanol Production Segment

Each of our ethanol production segment subsidiaries have credit facilities with lender groups that provide for term and revolving term loans to finance construction and operation of the production facilities.

The Green Plains Bluffton loan is comprised of a $70.0 million amortizing term loan and a $20.0 million revolving term loan. At March 31, 2012, $46.3 million related to the term loan was outstanding, along with the entire revolving term loan. The term loan requires monthly principal payments of approximately $0.6 million. The loans mature on November 19, 2013.

The Green Plains Central City loan is comprised of a $55.0 million amortizing term loan and a $30.5 million revolving term loan as well as a revolving credit supplement of up to $11.0 million. At March 31, 2012, $45.3 million related to the term loan was outstanding, along with $28.6 million on the revolving term loan and $10.1 million on the revolving credit supplement. The term loan requires monthly principal payments of $0.4 million. The term loan and the revolving term loan mature on July 1, 2016 and the revolver matures on June 29, 2012. We expect to renew this revolver before its maturity date.

The Green Plains Holdings II loan is comprised of a $26.4 million amortizing term loan and a $51.1 million revolving term loan. At March 31, 2012, $26.4 million was outstanding on the amortizing term loan, along with $50.7 million on the revolving term loan. The term loan requires quarterly principal payments of $1.5 million. The revolving term loan requires semi-annual principal payments of approximately $2.7 million. The maturity dates of the amortizing term loan and revolving term loan are July 1, 2016 and October 1, 2018, respectively.

The Green Plains Obion loan is comprised of a $60.0 million amortizing term loan and a revolving term loan of $37.4 million. At March 31, 2012, $23.3 million related to the term loan and $36.2 million on the revolving term loan was outstanding. The term loan requires quarterly principal payments of $2.4 million. The term loan matures on August 20, 2014 and the revolving term loan matures on September 1, 2018.

The Green Plains Ord loan is comprised of a $25.0 million amortizing term loan and a $13.0 million revolving term loan as well as a statused revolving credit supplement of up to $5.0 million. At March 31, 2012, $20.7 million related to the term loan was outstanding, $12.2 million on the revolving term loan, along with $3.3 million on the revolver. The term loan requires monthly principal payments of $0.2 million. The term loan and the revolving term loan mature on July 1, 2016 and the revolver matures on June 29, 2012. We expect to renew this revolver before its maturity date.

The Green Plains Otter Tail loan is comprised of a $30.3 million amortizing term loan, a $4.7 million revolver and a $19.2 million note payable. At March 31, 2012, $26.3 million related to the term loan, $4.7 million on the revolver and $18.9 million on the note payable were outstanding. The term loan requires monthly principal payments of $0.4 million and the note payable requires monthly principal payments of $0.3 million beginning October 1, 2014. The term loan matures on September 1, 2018 and the revolver matures on March 19, 2013. We expect to renew this revolver on or before its maturity date.

The Green Plains Shenandoah loan is comprised of a $30.0 million amortizing term loan and a $17.0 million revolving term loan. At March 31, 2012, $4.9 million related to the term loan was outstanding along with the entire $17.0 million on the revolving term loan. The term loan requires quarterly principal payments of $1.2 million. The term loan matures on May 20, 2013 and the revolving term loan matures on November 1, 2016.

The Green Plains Superior loan is comprised of a $23.5 million amortizing term loan and a $10.0 million revolving term loan. At March 31, 2012, $19.4 million related to the term loan was outstanding, along with the entire $10.0 million on the revolving term loan. The term loan requires quarterly principal payments of $1.4 million. The term loan matures on July 20, 2015 and the revolving term loan matures on July 1, 2017.

Each term loan, except for the Green Plains Holdings II and Green Plains Otter Tail agreements, has a provision that requires us to make annual special payments equal to a percentage ranging from 65% to 75% of the available free cash flow from the related entity’s operations (as defined in the respective loan agreements), subject to certain limitations. With certain exceptions, the revolving term loans within this segment are generally available for advances throughout the life of the commitment. Interest-only payments are due each month on all revolving term facilities until the final maturity date, with the exception of the Green Plains Obion loan, which requires additional semi-annual payments of $4.675 million beginning March 1, 2015.

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The term loans and revolving term loans bear interest at LIBOR plus 3.00% to 4.50% or lender-established prime rates. Some have established a floor on the underlying LIBOR index. In some cases, the lender may allow us to elect to pay interest at a fixed interest rate to be determined. As security for the loans, the lenders received a first-position lien on all personal property and real estate owned by the respective entity borrowing the funds, including an assignment of all contracts and rights pertinent to construction and on-going operations of the plant. Additionally, debt facilities of Green Plains Central City and Green Plains Ord are cross-collateralized. These borrowing entities are also required to maintain certain combined financial and non-financial covenants during the terms of the loans.

Green Plains Bluffton also received $22.0 million in Subordinate Solid Waste Disposal Facility Revenue Bond funds from the city of Bluffton, Indiana, of which $18.3 million remained outstanding at March 31, 2012. The revenue bond requires: semi-annual principal and interest payments of approximately $1.5 million through March 1, 2019; and a final principal and interest payment of $3.745 million on September 1, 2019. The revenue bond bears interest at 7.50% per annum.

Agribusiness Segment

The Green Plains Grain loans, executed on October 28, 2011, are comprised of a $30.0 million amortizing term loan and a $195.0 million revolving credit facility with various lenders to provide the agribusiness segment with additional term and working capital funding. The term loan and revolving credit facility mature on November 1, 2021 and October 28, 2013, respectively. Equal payments of principal sufficient to amortize the term loan in full over a 15-year period, plus interest, are due on the first day of every month with the remaining outstanding balance and all accrued interest due on the loan maturity date. The principal balance of each advance of the revolving credit facility shall be due and payable on the respective maturity date but no later than October 28, 2013. The term loan bears interest at a fixed rate of 6.00% per annum. Advances of the revolving credit facility are subject to interest charges at a rate per annum equal to the LIBOR rate for the outstanding period, or the base rate, plus the respective applicable margin. At March 31, 2012, $29.3 million on the term loan and $62.0 million on the various revolving loans were outstanding. As security for the amortizing term loan the lender received a first priority lien on certain real estate and other property owned by the subsidiaries within the agribusiness segment. As security for the revolving credit facility, the lender received a first priority lien on certain cash, inventory, machinery, accounts receivable and other assets owned by subsidiaries of the agribusiness segment.

We have entered into short-term inventory financing arrangements with a financial institution. At March 31, 2012, 3.0 million bushels of corn and 0.5 million bushels of soybeans had been designated as collateral under these contracts at an initial value of $24.7 million. We have accounted for the agreements as short-term notes, rather than sales, and have recorded our repurchase obligation at fair value at the end of each period. At March 31, 2012, grain inventory and the short-term notes payable were valued at $26.6 million.

Marketing and Distribution Segment

The Green Plains Trade loan is comprised of a senior secured revolving credit facility of up to $70.0 million, subject to a borrowing base of 85% of eligible receivables. At March 31, 2012, $53.9 million was outstanding on the revolving credit facility. The revolving credit facility expires on March 31, 2014 and bears interest at the lender’s commercial floating rate plus 2.5% or LIBOR plus 3.5%. As security for the loan, the lender received a first-position lien on accounts receivable, inventory and other collateral owned by Green Plains Trade.

Corporate Activities

We also have $90.0 million of 5.75% Convertible Senior Notes due 2015. The Notes represent senior, unsecured obligations, with interest payable on May 1 and November 1 of each year. The Notes may be converted into shares of common stock and cash in lieu of fractional shares of the common stock based on a conversion rate initially equal to 69.7788 shares of the common stock per $1,000 principal amount of Notes, which is equal to an initial conversion price of $14.33 per share. The conversion rate is subject to adjustment upon the occurrence of specified events. We may redeem for cash all, but not less than all, of the Notes at any time on and after November 1, 2013, if the last reported sale price of our common stock equals or exceeds 140% of the applicable conversion price for a specified time period, at a redemption price equal to 100% of the principal amount of the Notes, plus accrued and unpaid interest. Default with respect to any loan in excess of $10.0 million constitutes an event of default under the convertible senior notes, which could result in the convertible senior notes being declared due and payable.

In conjunction with the repurchase of common stock on March 9, 2012, the Company signed a one-year promissory note bearing 5% interest per annum in the amount of $27.2 million to a subsidiary of NTR plc.

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Contractual Obligations

Our contractual obligations as of March 31, 2012 were as follows (in thousands):

	Payments Due By Period
Contractual Obligations	Total		Less than 1 year		1-3 years		3-5 years		More than 5 years
Long-term and short-term debt obligations (1)	$	739,709	$	253,390	$	148,509	$	181,263	$	156,547
Interest and fees on debt obligations (2)		105,622		31,081		42,348		23,101		9,092
Operating lease obligations (3)		50,459		16,294		20,919		11,061		2,185
Deferred tax liabilities		60,294		—		—		—		60,294
Purchase obligations
Forward grain purchase contracts (4)		392,176		391,176		1,000		—		—
Other commodity purchase contracts (5)		24,761		24,761		—		—		—
Other		3,509		3,203		306		—		—
Total contractual obligations	$	1,376,530	$	719,905	$	213,082	$	215,425	$	228,118

(1) Includes the current portion of long-term debt and excludes the discount on long-term debt of $260 thousand.

(2) Interest amounts are calculated over the terms of the loans using current interest rates, assuming scheduled principle and interest amounts are paid pursuant to the debt agreements. Includes administrative and/or commitment fees on debt obligations.

(3) Operating lease costs are primarily for railcars and office space.

(4) Purchase contracts represent index-priced and fixed-price contracts. Index purchase contracts are valued at current quarter-end prices.

(5) Includes fixed-price ethanol, dried distillers grains and natural gas purchase contracts.

Item 3. Quantitative and Qualitative Disclosures About Market Risk.

We are exposed to various market risks, including changes in commodity prices and interest rates. Market risk is the potential loss arising from adverse changes in market rates and prices. In the ordinary course of business, we enter into various types of transactions involving financial instruments to manage and reduce the impact of changes in commodity prices and interest rates. At this time, we do not expect to have exposure to foreign currency risk as we expect to conduct all of our business in U.S. dollars.

Interest Rate Risk

We are exposed to market risk from changes in interest rates. Exposure to interest rate risk results primarily from holding term and revolving loans that bear variable interest rates. Specifically, we have $739.7 million outstanding in debt as of March 31, 2012, $460.6 million of which is variable-rate in nature. Interest rates on our variable-rate debt are determined based upon the market interest rate of either the lender’s prime rate or LIBOR, as applicable. A 10% change in interest rates would affect our interest cost on such debt by approximately $2.0 million per year in the aggregate. Other details of our outstanding debt are discussed in the notes to the consolidated financial statements included as a part of this report.

Commodity Price Risk

We produce ethanol, distillers grains and corn oil from corn and our business is sensitive to changes in the prices of each of these commodities. The price of corn is subject to fluctuations due to unpredictable factors such as weather; corn planted and harvested acreage; changes in national and global supply and demand; and government programs and policies. We use natural gas in the ethanol production process and, as a result, our business is also sensitive to changes in the price of natural gas. The price of natural gas is influenced by such weather factors as extreme heat or cold in the summer and winter, or other natural events like hurricanes in the spring, summer and fall. Other natural gas price factors include North American exploration and production, and the amount of natural gas in underground storage during both the injection and withdrawal seasons. Ethanol prices are sensitive to world crude-oil supply and demand; crude-oil refining capacity and utilization; government regulation; and consumer demand for alternative fuels. Distillers grains prices are sensitive to various demand factors such as numbers of livestock on feed, prices for feed alternatives, and supply factors, primarily production by ethanol plants and other sources.

We attempt to reduce the market risk associated with fluctuations in the price of corn, natural gas, ethanol, distillers grains and corn oil by employing a variety of risk management and economic hedging strategies. Strategies include the use of forward fixed-price physical contracts and derivative financial instruments, such as futures and options executed on the Chicago Board of Trade and the New York Mercantile Exchange.

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We focus on locking in operating margins based on a model that continually monitors market prices of corn, natural gas and other input costs against prices for ethanol and distillers grains at each of our production facilities. We create offsetting positions by using a combination of forward fixed-price physical purchases and sales contracts and derivative financial instruments. As a result of this approach, we frequently have gains on derivative financial instruments that are conversely offset by losses on forward fixed-price physical contracts or inventories and vice versa. In our ethanol production segment, gains and losses on derivative financial instruments are recognized each period in operating results, unless designated as cash flow hedges, while corresponding gains and losses on physical contracts are generally designated as normal purchases or normal sales contracts and are not recognized until quantities are delivered or utilized in production. For cash flow hedges, any ineffectiveness is recognized in current period results, while other unrealized gains and losses are deferred in accumulated other comprehensive income until gains and losses from the underlying hedged transaction are realized. In the event that it becomes probable that a forecasted transaction will not occur, we would discontinue cash flow hedge treatment, which would affect earnings. During the three months ended March 31, 2012, revenues and cost of goods sold included net losses from derivative financial instruments of $2.3 million and $3.6 million respectively. To the extent the net gains or losses from settled derivative instruments are related to hedging current period production, they are generally offset by physical commodity purchases or sales resulting in the realization of the intended operating margins. However, our results of operations are impacted when there is a mismatch of gains or losses associated with the change in fair value of derivative instruments at the reporting period when the physical commodity purchase or sales has not yet occurred since they are designated as a normal purchase or normal sale.

In our agribusiness segment, inventory positions, physical purchase and sale contracts, and financial derivatives are marked to market with gains and losses included in results of operations. The market value of derivative financial instruments such as exchange-traded futures and options has a high, but not perfect, correlation to the underlying market value of grain inventories and related purchase and sale contracts.

Ethanol Production Segment

A sensitivity analysis has been prepared to estimate our ethanol production segment exposure to ethanol, corn, distillers grains and natural gas price risk. Market risk related to these factors is estimated as the potential change in net income resulting from hypothetical 10% changes in prices of our expected corn and natural gas requirements, and ethanol and distillers grains output for a one-year period from March 31, 2012. This analysis includes the impact of risk management activities that result from our use of fixed-price purchase and sale contracts and derivatives. The results of this analysis, which may differ from actual results, are as follows (in thousands):

Commodity	Estimated Total Volume Requirements for the Next 12 Months		Unit of Measure	Net Income Effect of Approximate 10% Change in Price
Ethanol		740,000	Gallons	$	84,878
Corn		265,000	Bushels	$	84,769
Distillers grains		2,100	Tons (1)	$	19,601
Natural gas		20,300	MMBTU (2)	$	3,203

(1) Distillers grains quantities are stated on an equivalent dried ton basis.

(2) Millions of British Thermal Units

Corn Oil Production Segment

A sensitivity analysis has been prepared to estimate our corn oil production segment exposure to corn oil price risk. Market risk related to these factors is estimated as the potential change in net income resulting from hypothetical 10% changes in prices of our expected corn oil output for a one-year period from March 31, 2012. This analysis includes the impact of risk management activities that result from our use of fixed-price sale contracts. Market risk at March 31, 2012, based on the estimated net income effect resulting from a hypothetical 10% change in such prices, was approximately $1.3 million.

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Agribusiness Segment

The availability and price of agricultural commodities are subject to wide fluctuations due to unpredictable factors such as weather, plantings, foreign and domestic government farm programs and policies, changes in global demand created by population changes and changes in standards of living, and global production of similar and competitive crops. To reduce price risk caused by market fluctuations in purchase and sale commitments for grain and grain held in inventory, we enter into exchange-traded futures and options contracts that function as economic hedges. The market value of exchange-traded futures and options used for economic hedging has a high, but not perfect correlation, to the underlying market value of grain inventories and related purchase and sale contracts. The less correlated portion of inventory and purchase and sale contract market value, known as basis, is much less volatile than the overall market value of exchange-traded futures and tends to follow historical patterns. We manage this less volatile risk by constantly monitoring our position relative to the price changes in the market. In addition, inventory values are affected by the month-to-month spread relationships in the regulated futures markets, as we carry inventories over time. These spread relationships are also less volatile than the overall market value and tend to follow historical patterns, but also represent a risk that cannot be directly offset. Our accounting policy for our futures and options, as well as the underlying inventory positions and purchase and sale contracts, is to mark them to the market and include gains and losses in the consolidated statement of operations in sales and merchandising revenues.

A sensitivity analysis has been prepared to estimate agribusiness segment exposure to market risk of our commodity position (exclusive of basis risk). Our daily net commodity position consists of inventories related to purchase and sale contracts and exchange-traded contracts. The fair value of our position, which is a summation of the fair values calculated for each commodity by valuing each net position at quoted futures market prices, is approximately $158.9 thousand at March 31, 2012. Market risk at that date, based on the estimated net income effect resulting from a hypothetical 10% change in such prices, was approximately $22.0 thousand.

Item 4. Controls and Procedures.

Evaluation of Disclosure Controls and Procedures

We maintain disclosure controls and procedures that are designed to ensure that information required to be disclosed in the reports that we file or submit under the Securities Exchange Act of 1934, or Exchange Act, is recorded, processed, summarized and reported within the time periods specified in the SEC’s rules and forms, and that such information is accumulated and communicated to our management, including our Chief Executive Officer and Chief Financial Officer, as appropriate, to allow timely decisions regarding required financial disclosure.

As of the end of the period covered by this report, our management carried out an evaluation, under the supervision of and with the participation of our Chief Executive Officer and Chief Financial Officer, of the effectiveness of the design and operation of our disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e) under the Exchange Act). Our disclosure controls and procedures are designed to ensure that information required to be disclosed in the reports that we file or submit under the Exchange Act is recorded, processed, summarized and reported within the time periods specified in SEC rules and forms. These disclosure controls and procedures are designed to ensure that information required to be disclosed by us in the reports that it files or submits under the Exchange Act is accumulated and communicated to our management, including our Chief Executive Officer and Chief Financial Officer, as appropriate, to allow timely decisions regarding required financial disclosure. Based upon that evaluation, our management, including our Chief Executive Officer and the Chief Financial Officer, concluded that our disclosure controls and procedures were effective.

Changes in Internal Control over Financial Reporting

Our management is responsible for establishing and maintaining effective internal control over financial reporting to provide reasonable assurance regarding the reliability of our financial reporting and the preparation of our consolidated financial statements for external purposes in accordance with generally accepted accounting principles. In the first quarter of 2012, we implemented a process and information system enhancement, principally related to contract and risk management activities, in our trade operations that are reported as a part of the marketing and distribution segment. The process and information system resulted in modification to internal controls over the purchases, sales, accounts payable, accounts receivable, cash receipts and inventory management of ethanol. There were no other material changes in our internal control over financial reporting that occurred during the period covered by this quarterly report that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

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PART II – OTHER INFORMATION

Item 1. Legal Proceedings.

In April 2011, Aventine Renewable Energy, Inc. filed a complaint in the United States Bankruptcy Court for the District of Delaware in connection with its Chapter 11 bankruptcy naming as defendants Green Plains Renewable Energy, Inc., Green Plains Obion LLC, Green Plains Bluffton LLC, Green Plains VBV LLC and Green Plains Trade Group LLC. This action alleges $24.4 million of damages from preferential transfers or, in the alternative, $28.4 million of damages from fraudulent transfers under an ethanol marketing agreement and an unspecified amount of damages for a continuing breach of a termination agreement related to rail cars. In April 2012, the parties mutually agreed to a negotiated settlement whereby we agreed to a cash payment and the purchase of 20 million gallons of ethanol from Aventine over a four-month period beginning in May 2012. An after-tax charge of $2.4 million for the settlement was reflected in operations for the three months ended March 31, 2012.

Green Plains Bluffton LLC was issued a notice of violation under Section 113(a)(1) of the Clean Air Act by the EPA on July 1, 2011 for violations of the Indiana State Implementation Plan for exceeding NOx emission limits per hour and for operation of the thermal oxidizer below the required average temperature pursuant to the Federally Enforceable State Operating Permit issued to the facility by the Indiana Department of Environmental Management. Initially, the EPA proposed an initial fine of approximately $197 thousand. The matter was resolved with the payment of a fine significantly less than the initial proposal.

In addition to the above-described proceedings, we are currently involved in other litigation that has arisen in the ordinary course of business; however, we do not believe that any of this other litigation will have a material adverse effect on our financial position, results of operations or cash flows.

Item 1A. Risk Factors.

Our investors should consider the risks that could affect us and our business as set forth in Part I, Item 1A, “Risk Factors” of our annual report on Form 10-K for the year ended December 31, 2011. Although we have attempted to discuss key factors, our investors need to be aware that other risks may prove to be important in the future. New risks may emerge at any time and we cannot predict such risks or estimate the extent to which they may affect our financial performance. Investors should also consider the discussion of risks and the other information included in this quarterly report on Form 10-Q, including Cautionary Information Regarding Forward-Looking Information, which is included in Part I, Item 2, “Management’s Discussion and Analysis of Financial Condition and Results of Operations.”

The following risk factors, which modifies risk factors set forth in our annual report on Form 10-K for the year ended December 31, 2011, to include information related to potential price volatility of crude oil and an update regarding regulation of greenhouse gasses, should be considered in conjunction with the other information included in, or incorporated by reference in, this quarterly report on Form 10-Q.

Price volatility of each commodity that we buy and sell could each adversely affect our results of operations and our ability to operate at a profit.

Corn. Because ethanol competes with non-corn derived fuels, we generally are unable to pass along increases in corn costs to our customers. At certain levels, corn prices may make ethanol uneconomical to produce. There is significant price pressure on local corn markets caused by nearby ethanol plants, livestock industries and other corn consuming enterprises. Additionally, local corn supplies and prices could be adversely affected by rising prices for alternative crops, increasing input costs, changes in government policies, shifts in global markets, or damaging growing conditions such as plant disease or adverse weather.

Natural Gas. The prices for and availability of natural gas are subject to volatile market conditions. These market conditions often are affected by factors beyond our control, such as weather conditions, overall economic conditions, and foreign and domestic governmental regulation and relations. Significant disruptions in the supply of natural gas could impair our ability to manufacture ethanol for our customers. Furthermore, increases in natural gas prices or changes in our natural gas costs relative to natural gas costs paid by competitors may adversely affect our results of operations and financial position.

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Ethanol. Our revenues are dependent on market prices for ethanol. These market prices can be volatile as a result of a number of factors, including, but not limited to, the availability and price of competing fuels, the overall supply and demand for ethanol and corn, the price of gasoline and corn, and the level of government support.

Ethanol is marketed as a fuel additive to reduce vehicle emissions from gasoline, as an octane enhancer to improve the octane rating of the gasoline with which it is blended and, to a lesser extent, as a gasoline substitute. As a result, ethanol prices are influenced by the supply of and demand for gasoline. Our results of operations may be materially harmed if the demand for, or the price of, gasoline decreases. Conversely, a prolonged increase in the price of, or demand for, gasoline could lead the U.S. government to avoid limiting imported ethanol; the import tariff of $0.54 per gallon was allowed to expire on December 31, 2011.

Distillers Grains. Distillers grains compete with other protein-based animal feed products. The price of distillers grains may decrease when the prices of competing feed products decrease. The prices of competing animal feed products are based in part on the prices of the commodities from which these products are derived. Downward pressure on commodity prices, such as soybeans, will generally cause the price of competing animal feed products to decline, resulting in downward pressure on the price of distillers grains.

Historically, sales prices for distillers grains has tracked along with the price of corn. However, there have been occasions when the price increase for this co-product has lagged behind increases in corn prices. In addition, our distillers grains co-product competes with products made from other feedstocks, the cost of which may not have risen as corn prices have risen. Consequently, the price we may receive for distillers grains may not rise as corn prices rise, thereby lowering our cost recovery percentage relative to corn.

Due to industry increases in U.S. dry mill ethanol production, the production of distillers grains in the United States has increased dramatically, and this trend may continue. This may cause distillers grains prices to fall in the United States, unless demand increases or other market sources are found. To date, demand for distillers grains in the United States has increased roughly in proportion to supply. We believe this is because U.S. farmers use distillers grains as a feedstock, and distillers grains are slightly less expensive than corn, for which it is a substitute. However, if prices for distillers grains in the United States fall, it may have an adverse effect on our business.

Corn Oil. Industrial uses for corn oil include feedstock for biodiesel, livestock feed additives, rubber substitutes, rust preventatives, inks, textiles, soaps and insecticides. Corn oil is generally marketed as a feedstock for biodiesel and, therefore, the price of corn oil is affected by demand for biodiesel. In general, corn oil prices follow the same price trends as heating oil and soybean oil. Corn oil revenues historically have not been significant to our business; however, our business may be materially affected by price volatility of corn oil in the future as we expand our corn oil production.

Crude Oil. In addition to the commodities that we produce, buy and sell related to ethanol production, we purchase and sell crude oil to increase the utilization of our railcar fleet. Crude oil revenues historically have not been significant to our business; however, our business may be materially affected by price volatility of crude oil in the future as we may increase the volume of our crude oil purchases and sales.

Our business is affected by the regulation of greenhouse gases, or GHG, and climate change. New climate change regulations could impede our ability to successfully operate our business.

Our plants emit carbon dioxide as a by-product of the ethanol production process. In 2007, the U.S. Supreme Court classified carbon dioxide as an air pollutant under the Clean Air Act in a case seeking to require the EPA to regulate carbon dioxide in vehicle emissions. On February 3, 2010, the EPA released its final regulations on RFS 2. We believe these final regulations grandfather our plants at their current operating capacity, though expansion of our plants will need to meet a threshold of a 20% reduction in GHG emissions from a 2005 baseline measurement for the ethanol over current capacity to be eligible for the RFS 2 mandate. The EPA issued its final rule on GHG emissions from stationary sources under the Clean Air Act in May 2010. These final rules may require us to apply for additional permits for our ethanol plants. In order to expand capacity at our plants, we may have to apply for additional permits, install advanced technology, or reduce drying of certain amounts of distillers grains. We may also be required to install carbon dioxide mitigation equipment or take other steps unknown to us at this time in order to comply with other future law or regulation. Compliance with future law or regulation of carbon dioxide, or if we choose to expand capacity at certain of our plants, compliance with then-current regulation of carbon dioxide, could be costly and may prevent us from operating our plants as profitably, which may have an adverse impact on our operations, cash flows and financial position.

40

The California Air Resources Board, or CARB, has adopted a Low Carbon Fuel Standard, or LCFS, requiring a 10% reduction in GHG emissions from transportation fuels by 2020. Additionally, an Indirect Land Use Change, or ILUC, component is included in the lifecycle GHG emissions calculation. On December 29, 2011, the U.S. District Court for the Eastern District of California issued several rulings in federal lawsuits challenging the LCFS. One of the rulings preliminarily prevents CARB from enforcing these regulations during the pending litigation. On January 23, 2012, CARB unsuccessfully attempted to appeal these rulings in the U.S. District Court for the Eastern District of California and on January 26, 2012 filed another appeal with the Ninth Circuit Court of Appeals. On April 22, 2012, the Court of Appeals granted the request to put a hold on the December 29, 2011 ruling, which was to have taken effect on January 1, 2012. The decision allows CARB to continue implementation and resume enforcement of the LCFS. While this standard may continue to be challenged, implementation of such a standard may have an adverse impact on our market for corn-based ethanol in California if it is determined that corn-based ethanol fails to achieve lifecycle GHG emission reductions.

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

Employees surrender shares upon the vesting of restricted stock grants to satisfy payroll tax withholding obligations. The following table sets forth the shares that were surrendered by month during the first quarter of 2012.

Month	Total Number of Shares Withheld		Average Price Paid per Share
January		—	$	—
February		58,162		11.27
March		35,325		10.56
Total		93,487	$	11.00

On March 9, 2012, we repurchased 3.7 million shares of common stock for $37.2 million from a subsidiary of NTR plc, which was previously our largest shareholder. We do not have a share repurchase program and do not intend to retire the repurchased shares.

Item 3. Defaults Upon Senior Securities.

None.

Item 4. Mine Safety Disclosures.

Not applicable.

Item 5. Other Information.

None.

41

Item 6. Exhibits.

Exhibit Index

Exhibit No.	Description
10.1	First Amendment to Amended and Restated Master Loan Agreement, dated February 16, 2012, by and among Green Plains Bluffton LLC and AgStar Financial Services, PCA (Incorporated by reference to Exhibit 10.5(c) of the Company’s Annual Report on Form 10-K filed February 17, 2012)
10.2	First Amendment to Credit Agreement dated January 6, 2012 by and among Green Plains Grain Company LLC, Green Plains Grain Company TN LLC, Green Plains Essex Inc., BNP Paribas and the Required Lenders (Incorporated by reference to Exhibit 10.26(k) of the Company’s Annual Report on Form 10-K filed February 17, 2012)
10.3(a)	Amended and Restated Credit Agreement, dated February 9, 2012 by and among Green Plains Holdings II, various lenders and CoBank, ACB (as Administrative Agent, Syndication Agent and Lead Arranger) (Incorporated by reference to Exhibit 10.27(a) of the Company’s Annual Report on Form 10-K filed February 17, 2012)
10.3(b)	Amended and Restated Support and Subordination Agreement, dated February 9, 2012 by and among Green Plains Holdings II, as Borrower, Green Plains Renewable Energy, Inc., as Parent, and CoBank, ACB, as Administrative Agent (Incorporated by reference to Exhibit 10.27(b) of the Company’s Annual Report on Form 10-K filed February 17, 2012)
10.3(c)	Security Agreement, dated February 9, 2012 by and among Green Plains Holdings II (the Grantor) and CoBank, ACB (the Secured Party) (Incorporated by reference to Exhibit 10.27(c) of the Company’s Annual Report on Form 10-K filed February 17, 2012)
10.3(d)	Second Amendment to Mortgage, dated February 9, 2012 by and among, Green Plains Holdings II and CoBank ACB (Incorporated by reference to Exhibit 10.27(d) of the Company’s Annual Report on Form 10-K filed February 17, 2012)
10.3(e)	Second Amendment to Amended and Restated Real Estate Mortgage, dated February 9, 2012 by and among Green Plains Holdings II and CoBank, ACB (Incorporated by reference to Exhibit 10.27(e) of the Company’s Annual Report on Form 10-K filed February 17, 2012)
10.4	Stock Repurchase Agreement dated February 28, 2012 between Greenstar Investments LLC, Greenstar North America Holdings, Inc. and Green Plains Renewable Energy, Inc. (Incorporated by reference to Exhibit 10.1 of the Company’s Current Report on Form 8-K filed March 2, 2012)
31.1	Certification of Chief Executive Officer pursuant to Rule 13a-14(a) and Section 302 of the Sarbanes-Oxley Act of 2002
31.2	Certification of Chief Financial Officer pursuant to Rule 13a-14(a) and Section 302 of the Sarbanes-Oxley Act of 2002
32.1	Certification of Chief Executive Officer pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002
32.2	Certification of Chief Financial Officer pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002
101	The following information from Green Plains Renewable Energy, Inc.’s Quarterly Report on Form 10-Q for the quarterly period ended March 31, 2012, formatted in Extensible Business Reporting Language (XBRL): (i) Consolidated Balance Sheets, (ii) Consolidated Statements of Operations, (iii) Consolidated Statements of Comprehensive Income (Loss), (iv) Consolidated Statements of Cash Flows, and (v) the Notes to Consolidated Financial Statements (tagged as blocks of text)

42

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 hereunto duly authorized.

	GREEN PLAINS RENEWABLE ENERGY, INC. (Registrant)
Date: May 1, 2012	By:	/s/ Todd A. Becker
		Todd A. Becker President and Chief Executive Officer (Principal Executive Officer)

Date: May 1, 2012	By:	/s/ Jerry L. Peters
		Jerry L. Peters Chief Financial Officer (Principal Financial Officer)

43

EX-31.1

Exhibit 31.1

CERTIFICATION OF CHIEF EXECUTIVE OFFICER

PURSUANT TO RULE 13a-14(a) AND SECTION 302 OF THE SARBANES-OXLEY ACT OF 2002

I, Todd A. Becker, certify that:

1. I have reviewed this Quarterly Report on Form 10-Q of Green Plains Renewable Energy, Inc.;

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f) for the registrant and have:

a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5. The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: May 1, 2012	/s/ Todd A. Becker
	Todd A. Becker
	President and Chief Executive Officer (Principal Executive Officer)

EX-31.2

Exhibit 31.2

CERTIFICATION OF CHIEF FINANCIAL OFFICER

PURSUANT TO RULE 13a-14(a) AND SECTION 302 OF THE SARBANES-OXLEY ACT OF 2002

I, Jerry L. Peters, certify that:

1. I have reviewed this Quarterly Report on Form 10-Q of Green Plains Renewable Energy, Inc.;

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f) for the registrant and have:

a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5. The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: May 1, 2012	/s/ Jerry L. Peters
	Jerry L. Peters
	Chief Financial Officer (Principal Financial Officer)

EX-32.1

Exhibit 32.1

CERTIFICATION OF CHIEF EXECUTIVE OFFICER PURSUANT TO 18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report of Green Plains Renewable Energy, Inc. (the “Company”) on Form 10-Q for the fiscal quarter ended March 31, 2012 as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Todd A. Becker, President and Chief Executive Officer of the Company, certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that to my knowledge:

1) The Report fully complies with the requirements of Sections 13(a) or 15(d) of the Securities Exchange Act of 1934; and

2) The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

Date: May 1, 2012	/s/ Todd A. Becker
	Todd A. Becker
	President and Chief Executive Officer

EX-32.2

Exhibit 32.2

CERTIFICATION OF CHIEF FINANCIAL OFFICER PURSUANT TO 18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report of Green Plains Renewable Energy, Inc. (the “Company”) on Form 10-Q for the fiscal quarter ended March 31, 2012 as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Jerry L. Peters, Chief Financial Officer of the Company, certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that to my knowledge:

1) The Report fully complies with the requirements of Sections 13(a) or 15(d) of the Securities Exchange Act of 1934; and

2) The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

Date: May 1, 2012	/s/ Jerry L. Peters
	Jerry L. Peters
	Chief Financial Officer

XML

Fair Value Disclosures

3 Months Ended

Mar. 31, 2012

Fair Value Disclosures [Abstract]

Fair Value Disclosures

2.FAIR VALUE DISCLOSURES

The following methods, assumptions and valuation techniques were used in estimating the fair value of the Company’s financial instruments:

Level 1 – unadjusted quoted prices in active markets for identical assets or liabilities that the Company has the ability to access at the measurement date. Level 1 unrealized gains and losses on commodity derivatives relate to exchange-traded open trade equity and option values in the Company’s brokerage accounts.

Level 2 – directly or indirectly observable inputs such as quoted prices for similar assets or liabilities in active markets other than quoted prices included within Level 1; quoted prices for identical or similar assets in markets that are not active; and other inputs that are observable or can be substantially corroborated by observable market data by correlation or other means. Grain inventories held for sale in the agribusiness segment are valued at nearby futures values, plus or minus nearby basis levels.

Level 3 – unobservable inputs that are supported by little or no market activity and that are a significant component of the fair value of the assets or liabilities. The Company currently does not have any recurring Level 3 financial instruments.

There have been no changes in valuation techniques and inputs used in measuring fair value. The following tables set forth the Company’s assets and liabilities by level that were accounted for the periods indicated (in thousands):

			Fair Value Measurements at March 31, 2012
			Quoted Prices in Active Markets for Identical Assets		Significant Other Observable Inputs		Reclassification for Balance Sheet
			(Level 1)		(Level 2)		Presentation		Total
Assets
	Cash and cash equivalents		$	134,989	$	-	$	-	$	134,989
	Restricted cash			27,023		-		-		27,023
	Margin deposits			22,783		-		-		22,783
	Inventories carried at market			-		96,454		-		96,454
	Unrealized gains on derivatives			3,225		11,079		(8,724)		5,580
		Total assets measured at fair value	$	188,020	$	107,533	$	(8,724)	$	286,829
Liabilities
	Unrealized losses on derivatives		$	8,951	$	7,231	$	(8,724)	$	7,458
	Inventory financing arrangements			-		26,582		-		26,582
	Other			96		-		-		96
		Total liabilities measured at fair value	$	9,047	$	33,813	$	(8,724)	$	34,136

			Fair Value Measurements at December 31, 2011
			Quoted Prices in Active Markets for Identical Assets		Significant Other Observable Inputs		Reclassification for Balance Sheet
			(Level 1)		(Level 2)		Presentation		Total
Assets
	Cash and cash equivalents		$	174,988	$	-	$	-	$	174,988
	Restricted cash			21,820		-		-		21,820
	Inventories carried at market			-		112,948		-		112,948
	Unrealized gains on derivatives			15,710		6,010		(4,292)		17,428
		Total assets measured at fair value	$	212,518	$	118,958	$	(4,292)	$	327,184
Liabilities
	Unrealized losses on derivatives		$	2,828	$	5,287	$	(2,698)	$	5,417
	Margin deposits			1,594		-		(1,594)		-
	Inventory financing arrangements			-		8,894		-		8,894
	Other			71		-		-		71
		Total liabilities measured at fair value	$	4,493	$	14,181	$	(4,292)	$	14,382

The Company believes the fair value of its debt approximates book value, which was $739.7 million and $636.8 million at March 31, 2012 and December 31, 2011, respectively. The Company also believes the fair value of its accounts receivable and accounts payable approximate book value, which were $92.7 million and $96.9 million, respectively, at March 31, 2012 and $106.2 million and $172.3 million, respectively, at December 31, 2011.

Although the Company currently does not have any Level 3 financial measurements, the fair values of the tangible assets and goodwill acquired in previous reporting periods represent Level 3 measurements and were derived using a combination of the income approach, the market approach and the cost approach as considered appropriate for the specific assets being valued.

XML

Basis Of Presentation And Description Of Business

3 Months Ended

Mar. 31, 2012

Basis Of Presentation And Description Of Business [Abstract]

Basis Of Presentation And Description Of Business

GREEN PLAINS RENEWABLE ENERGY, INC. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(unaudited)

1.BASIS OF PRESENTATION, DESCRIPTION OF BUSINESS AND SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

References to the Company

References to “Green Plains” or the “Company” in the consolidated financial statements and in these notes to the consolidated financial statements refer to Green Plains Renewable Energy, Inc., an Iowa corporation, and its subsidiaries.

Consolidated Financial Statements

The consolidated financial statements include the accounts of the Company, its wholly-owned subsidiaries and entities which it controls. All significant intercompany balances and transactions have been eliminated on a consolidated basis for reporting purposes. Unconsolidated entities are included in the financial statements on an equity basis. Certain amounts previously reported have been reclassified to conform to the current period presentation. Results for the interim periods presented are not necessarily indicative of results to be expected for the entire year.

The accompanying unaudited consolidated financial statements have been prepared in conformity with U.S. generally accepted accounting principles, or GAAP, for interim financial information and the instructions to Form 10-Q and Article 10 of Regulation S-X. Accordingly, they do not include all of the information and footnotes required by GAAP for complete financial statements. The financial statements should be read in conjunction with the Company’s annual report filed on Form 10-K for the year ended December 31, 2011.

The unaudited financial information reflects all adjustments which are, in the opinion of management, necessary for a fair presentation of the results of operations, financial position and cash flows for the periods presented. The adjustments are of a normal recurring nature, except as otherwise noted.

Use of Estimates in the Preparation of Consolidated Financial Statements

The preparation of consolidated financial statements in conformity with GAAP requires management to make certain estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the consolidated financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates.

Description of Business

Green Plains is North America’s fourth largest ethanol producer. The Company markets and distributes approximately one billion gallons of ethanol on an annual basis, including 740 million gallons per year, or mmgy, of production capacity from its nine ethanol plants. The Company also markets corn oil and distillers grains produced at its ethanol plants. Additionally, the Company owns and operates grain handling and storage assets and provides complementary agronomy services to local grain producers through its agribusiness segment. The Company owns and operates nine blending and terminaling facilities with approximately 625 mmgy of total throughput capacity. The Company is a partner in a joint venture that was formed to commercialize advanced photo-bioreactor technologies for the growing and harvesting of algal biomass.

Revenue Recognition

The Company recognizes revenue when all of the following criteria are satisfied: persuasive evidence of an arrangement exists; risk of loss and title transfer to the customer; the price is fixed and determinable; and collectability is reasonably assured.

For sales of ethanol and distillers grains by the Company’s marketing business, revenue is recognized when title to the product and risk of loss transfer to an external customer. Revenues related to marketing operations for third parties are recorded on a gross basis in the consolidated financial statements as Green Plains Trade takes title to the product and assumes risk of loss. Unearned revenue is reflected on the consolidated balance sheets for goods in transit for which the Company has received payment and title has not been transferred to the customer. Revenues from BlendStar’s biofuel terminal operations, which include ethanol transload and splash blending services, are recognized as these services are rendered.

The Company routinely enters into fixed-price, physical-delivery ethanol sales agreements. In certain instances, the Company intends to settle the transaction by open market purchases of ethanol rather than by delivery from its own production. These transactions are reported net as a component of revenues. Revenues also include realized gains and losses on related derivative financial instruments, ineffectiveness on cash flow hedges, and reclassifications of realized gains and losses on effective cash flow hedges from accumulated other comprehensive income (loss).

Sales of agricultural commodities, fertilizers and other similar products are recognized when title to the product and risk of loss transfer to the customer, which is dependent on the agreed upon sales terms with the customer. These sales terms provide for passage of title either at the time shipment is made or at the time the commodity has been delivered to its destination and final weights, grades and settlement prices have been agreed upon with the customer. Shipping and handling costs are presented gross in the statements of operations with amounts billed included in revenues and also as a component of cost of goods sold. Revenues from grain storage are recognized as services are rendered. Revenues related to grain merchandising are presented gross.

Cost of Goods Sold

Cost of goods sold includes costs for direct labor, materials and certain plant overhead costs. Direct labor includes all compensation and related benefits of non-management personnel involved in the operation of the Company’s ethanol plants. Grain purchasing and receiving costs, other than labor costs for grain buyers and scale operators, are also included in cost of goods sold. Direct materials consist of the costs of corn feedstock, denaturant, and process chemicals. Corn feedstock costs include unrealized gains and losses on related derivative financial instruments not designated as cash flow hedges, inbound freight charges, inspection costs and transfer costs. Corn feedstock costs also include realized gains and losses on related derivative financial instruments, ineffectiveness on cash flow hedges, and reclassifications of realized gains and losses on effective cash flow hedges from accumulated other comprehensive income (loss). Plant overhead costs primarily consist of plant utilities, plant depreciation and outbound freight charges. Shipping costs incurred directly by the Company, including railcar lease costs, are also reflected in cost of goods sold.

The Company uses exchange-traded futures and options contracts to minimize the effects of changes in the prices of agricultural commodities on its agribusiness segment’s grain inventories and forward purchase and sales contracts. Exchange-traded futures and options contracts are valued at quoted market prices. Commodity inventories, forward purchase contracts and forward sale contracts in the agribusiness segment are valued at market prices, where available, or other market quotes adjusted for differences, primarily transportation, between the exchange-traded market and the local markets on which the terms of the contracts are based. Changes in the market value of grain inventories, forward purchase and sale contracts, and exchange-traded futures and options contracts in the agribusiness segment, are recognized in earnings as a component of cost of goods sold. These contracts are predominantly settled in cash. The Company is exposed to loss in the event of non-performance by the counter-party to forward purchase and forward sales contracts.

Derivative Financial Instruments

To minimize the risk and the effects of the volatility of commodity price changes primarily related to corn, ethanol and natural gas, the Company uses various derivative financial instruments, including exchange-traded futures, and exchange-traded and over-the-counter options contracts. The Company monitors and manages this exposure as part of its overall risk management policy. As such, the Company seeks to reduce the potentially adverse effects that the volatility of these markets may have on its operating results. The Company may take hedging positions in these commodities as one way to mitigate risk. While the Company attempts to link its hedging activities to purchase and sales activities, there are situations where these hedging activities can themselves result in losses.

By using derivatives to hedge exposures to changes in commodity prices, the Company has exposures on these derivatives to credit and market risk. The Company is exposed to credit risk that the counterparty might fail to fulfill its performance obligations under the terms of the derivative contract. The Company minimizes its credit risk by entering into transactions with high quality counterparties, limiting the amount of financial exposure it has with each counterparty and monitoring the financial condition of its counterparties. Market risk is the risk that the value of the financial instrument might be adversely affected by a change in commodity prices or interest rates. The Company manages market risk by incorporating monitoring parameters within its risk management strategy that limit the types of derivative instruments and derivative strategies the Company uses, and the degree of market risk that may be undertaken by the use of derivative instruments.

The Company evaluates its contracts that involve physical delivery to determine whether they may qualify for the normal purchases or normal sales exemption and are expected to be used or sold over a reasonable period in the normal course of business. Any contracts that do not meet the normal purchase or sales criteria are recorded at fair value with the change in fair value recorded in operating income unless the contracts qualify for, and the Company elects, hedge accounting treatment.

Certain qualifying derivatives within the ethanol production segment are designated as cash flow hedges. Prior to entering into cash flow hedges, the Company evaluates the derivative instrument to ascertain its effectiveness. For cash flow hedges, any ineffectiveness is recognized in current period results, while other unrealized gains and losses are reflected in accumulated other comprehensive income until gains and losses from the underlying hedged transaction are realized. In the event that it becomes probable that a forecasted transaction will not occur, the Company would discontinue cash flow hedge treatment, which would affect earnings. These derivative financial instruments are recognized in current assets or other current liabilities at fair value.

The Company hedges its exposures to changes in the value of ethanol inventory and designates certain qualifying derivatives as fair value hedges. The carrying amount of the hedged inventory is adjusted through current period results for changes in the fair value arising from changes in ethanol prices.  Any ineffectiveness is recognized in current period results to the extent that the change in the fair value of the inventory is not offset by the change in the fair value of the derivative.

Recent Accounting Pronouncements

Effective January 1, 2012, the Company adopted the third phase of amended guidance in ASC Topic 820, Fair Value Measurements and Disclosures. The amended guidance clarifies the application of existing fair value measurement 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 Company currently is not impacted by the additional disclosure requirements as it does not have any recurring Level 3 measurements.

Effective January 1, 2012, the Company adopted the amended guidance in ASC Topic 220, Comprehensive Income. This accounting standards update is aimed at increasing the prominence of other comprehensive income in the financial statements by eliminating the option to present other comprehensive income in the statement of stockholders’ equity. The Company has elected to present net income and other comprehensive income in two separate but consecutive statements. The updated presentation, which has been implemented retroactively for all comparable periods presented, did not impact the Company’s financial position or results of operations.

Effective January 1, 2012, the Company adopted the amended guidance in ASC Topic 350, Intangibles – Goodwill and Other. The amended guidance permits an entity to first assess qualitative factors to determine whether it is more likely than not that the fair value of a reporting unit is less than its carrying amount as a basis for determining whether it is necessary to perform the two-step goodwill impairment test. The more-likely-than-not threshold is defined as having a likelihood of more than 50 percent. The Company has determined that the changes to the accounting standards do not impact its disclosure or reporting requirements.

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Consolidated Balance Sheets (USD $) In Thousands, unless otherwise specified	Mar. 31, 2012	Dec. 31, 2011
ASSETS
Cash and cash equivalents	$ 134,989	$ 174,988
Restricted cash	24,823	19,619
Accounts receivable, net of allowances of $309 and $263, respectively	92,702	106,198
Inventories	250,925	229,070
Prepaid expenses and other	5,715	8,610
Deferred income taxes	25,634	14,828
Deposits	3,665	5,679
Derivative financial instruments	28,363	17,428
Total current assets	566,816	576,420
Property and equipment, net of accumulated depreciation of $138,809 and $125,798, respectively	770,298	776,789
Goodwill	40,877	40,877
Other assets	25,695	26,742
Total assets	1,403,686	1,420,828
LIABILITIES AND STOCKHOLDERS' EQUITY
Accounts payable	96,852	172,328
Accrued and other liabilities	24,685	29,825
Unearned revenue	18,198	15,453
Short-term borrowings	169,603	69,599
Current maturities of long-term debt	83,787	73,760
Total current liabilities	393,125	360,965
Long-term debt	486,319	493,407
Deferred income taxes	60,294	55,970
Other liabilities	4,948	5,129
Total liabilities	944,686	915,471
Stockholders' equity
Common stock, $0.001 par value; 75,000,000 shares authorized; 00,000,000 and 36,413,611 shares issued, and 00,000,000 and 32,913,611 shares outstanding, respectively	37	36
Additional paid-in capital	441,781	440,469
Retained earnings	83,069	95,761
Accumulated other comprehensive income (loss)	(320)	(2,953)
Treasury stock, 7,200,000 and 3,500,000 shares, respectively	(65,808)	(28,201)
Total Green Plains stockholders' equity	458,759	505,112
Noncontrolling interests	241	245
Total stockholders' equity	459,000	505,357
Total liabilities and stockholders' equity	$ 1,403,686	$ 1,420,828

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Consolidated Statements Of Comprehensive Income (Parenthetical) (USD $) In Thousands, unless otherwise specified	3 Months Ended
	Mar. 31, 2012	Mar. 31, 2011
Consolidated Statements Of Comprehensive Income (Loss) [Abstract]
Tax (expense) benefit, unrealized gains on derivatives	$ (25)	$ 2,964
Tax (expense) benefit, reclassification of realized losses on derivatives	$ 1,491	$ 364

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Consolidated Statements Of Cash Flows (USD $) In Thousands, unless otherwise specified	3 Months Ended
	Mar. 31, 2012	Mar. 31, 2011
Cash flows from operating activities:
Net income	$ (12,696)	$ 7,531
Adjustments to reconcile net income to net cash provided (used) by operating activities:
Depreciation and amortization	13,158	12,003
Amortization of debt issuance costs	775	578
Deferred income taxes	(6,482)	1,617
Stock-based compensation expense	1,171	1,101
Undistributed equity in loss of affiliates	578	63
Allowance for doubtful accounts	46	14
Changes in operating assets and liabilities before effects of business combinations:
Accounts receivable	13,534	(226)
Inventories	(21,477)	(26,454)
Deposits	2,014	(2,549)
Derivative financial instruments	(8,264)	(7,797)
Prepaid expenses and other assets	2,895	(3,559)
Accounts payable and accrued liabilities	(80,716)	(77,751)
Unearned revenues	2,745	4,326
Other	(172)	(92)
Net cash provided by operating activities	(92,891)	(91,195)
Cash flows from investing activities:
Purchases of property and equipment	(5,660)	(11,570)
Acquisition of businesses, net of cash acquired	(1,490)	(6,106)
Other		(468)
Net cash used by investing activities	(7,150)	(18,144)
Cash flows from financing activities:
Proceeds from the issuance of long-term debt	16,000	67,004
Payments of principal on long-term debt	(13,080)	(91,226)
Proceeds from short-term borrowings	782,086	853,205
Payments on short-term borrowings	(710,653)	(818,237)
Payments for repurchase of common stock	(10,445)
Change in restricted cash	(5,204)	17,628
Payments of loan fees	(292)	(402)
Other	1,630	45
Net cash provided (used) by financing activities	60,042	28,017
Net change in cash and equivalents	(39,999)	(81,322)
Cash and cash equivalents, beginning of period	174,988	233,205
Cash and cash equivalents, end of period	134,989	151,883
Supplemental disclosures of cash flow:
Cash paid for income taxes	457	441
Cash paid for interest	7,032	7,884
Supplemental noncash investing and financing activities:
Assets acquired in acquisitions and mergers	1,590	61,015
Less: liabilities assumed	(100)	(54,909)
Net assets acquired	1,490	6,106
Short-term note payable issued to repurchase common stock	$ 27,162

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Consolidated Balance Sheets (Parenthetical) (USD $) In Thousands, except Share data, unless otherwise specified	3 Months Ended
	Mar. 31, 2012	Dec. 31, 2011
Consolidated Balance Sheets [Abstract]
Accounts receivable, allowances	$ 309	$ 263
Accumulated depreciation	$ 138,809	$ 125,798
Common stock, par value	$ 0.001	$ 0.001
Common stock, shares authorized	75,000,000	75,000,000
Common stock, shares issued	36,790,315	36,413,611
Common stock, shares outstanding	29,590,315	32,913,611
Treasury stock, shares	7,200,000	3,500,000

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Income Taxes

3 Months Ended

Mar. 31, 2012

Income Taxes [Abstract]

Income Taxes

11.INCOME TAXES

The Company records income tax expense or benefit during interim periods based on its best estimate of the annual effective tax rate. Certain items are given discrete period treatment and, as a result, the tax effects of such items are reported in full in the relevant interim period.

Income taxes for the three months ended March 31, 2012 was a benefit of $8.0 million compared to an expense of $4.4 million for the same period in 2011.The effective tax rate (calculated as the ratio of income tax expense to income before income taxes) was approximately 39% and 37% for the first three months of 2012 and 2011, respectively. The effective tax rate for the three months ended March 31, 2011, reflects the release of a portion of valuation allowances provided against certain of the Company’s deferred tax assets, primarily federal and state net operating losses and tax credits due to anticipated income in future periods.

The Company’s unrecognized tax benefits at March 31, 2012 and December 31, 2011 were $0.1 million. There was no change in the Company’s liabilities related to unrecognized tax benefits during the first three months of 2012.

The 2012 annual effective tax rate can be affected as a result of variances among the estimates and amounts of full-year sources of taxable income (among the various states), the realization of tax credits, adjustments that may arise from the resolution of tax matters under review, variances in the release of valuation allowances and the Company’s assessment of its liability for uncertain tax positions.

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Document And Entity Information	3 Months Ended
	Mar. 31, 2012	Apr. 27, 2012
Document And Entity Information [Abstract]
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Mar. 31, 2012
Document Fiscal Period Focus	Q1
Document Fiscal Year Focus	2012
Entity Registrant Name	Green Plains Renewable Energy, Inc.
Entity Central Index Key	0001309402
Current Fiscal Year End Date	--12-31
Entity Filer Category	Accelerated Filer
Entity Common Stock, Shares Outstanding		29,583,902
Trading Symbol	gpre

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Commitments And Contingencies

3 Months Ended

Mar. 31, 2012

Commitments And Contingencies [Abstract]

Commitments And Contingencies

12.COMMITMENTS AND CONTINGENCIES

Operating Leases

The Company leases certain facilities and parcels of land under agreements that expire at various dates. For accounting purposes, rent expense is based on a straight-line amortization of the total payments required over the lease term. The Company incurred lease expenses of $4.4 million and $3.7 million during the three months ended March 31, 2012 and 2011, respectively. Aggregate minimum lease payments under these agreements for the remainder of 2012 and in future fiscal years are as follows (in thousands):

Year Ending December 31,		Amount
	2012	$	12,424
	2013		14,829
	2014		8,261
	2015		6,589
	2016		5,376
	Thereafter		2,980
	Total	$	50,459

Commodities

As of March 31, 2012, the Company had contracted for future grain deliveries valued at approximately $392.2 million, natural gas deliveries valued at approximately $2.1 million, ethanol product deliveries valued at approximately $21.6 million and distillers grains product deliveries valued at approximately $1.0 million.

Legal

In April 2011, Aventine Renewable Energy, Inc. filed a complaint in the United States Bankruptcy Court for the District of Delaware in connection with its Chapter 11 bankruptcy naming as defendants Green Plains Renewable Energy, Inc., Green Plains Obion LLC, Green Plains Bluffton LLC, Green Plains VBV LLC and Green Plains Trade Group LLC. This action alleged $24.4 million of damages from preferential transfers or, in the alternative, $28.4 million of damages from fraudulent transfers under an ethanol marketing agreement and an unspecified amount of damages for a continuing breach of a termination agreement related to rail cars. In April 2012, the parties mutually agreed to a negotiated settlement whereby the Company agreed to a cash payment and the purchase of 20 million gallons of ethanol from Aventine over a four-month period beginning in May 2012. An after-tax charge of $2.4 million for the settlement was reflected in operations for the three months ended March 31, 2012.

In addition to the above-described proceeding, the Company is currently involved in other litigation that has arisen in the ordinary course of business, but it does not believe that any other pending litigation will have a material adverse effect on its financial position, results of operations or cash flows

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Consolidated Statements Of Operations (USD $) In Thousands, except Share data, unless otherwise specified	3 Months Ended
	Mar. 31, 2012	Mar. 31, 2011
Consolidated Statements Of Operations [Abstract]
Revenues	$ 775,395	$ 812,327
Cost of goods sold	766,625	774,703
Gross profit	8,770	37,624
Selling, general and administrative expenses	19,861	17,628
Operating income	(11,091)	19,996
Other income (expense)
Interest income	39	91
Interest expense	(9,067)	(8,132)
Other, net	(578)	(63)
Total other expense	(9,606)	(8,104)
Income before income taxes	(20,697)	11,892
Income tax expense	(8,001)	4,361
Net income	(12,696)	7,531
Net (income) loss attributable to noncontrolling interests	4	210
Net income attributable to Green Plains	$ (12,692)	$ 7,741
Earnings per share:
Income attributable to Green Plains stockholders - basic	$ (0.39)	$ 0.21
Income attributable to Green Plains stockholders - diluted	$ (0.39)	$ 0.20
Weighted average shares outstanding:
Basic	32,238	36,199
Diluted	32,238	42,764

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Goodwill

3 Months Ended

Mar. 31, 2012

Goodwill [Abstract]

Goodwill

5.GOODWILL

The Company did not have any changes in the total carrying amount of goodwill during the three months ended March 31, 2012, which was $40.9 million. Goodwill of $30.3 million is attributable to the ethanol production segment and $10.6 million is attributable to the marketing and distribution segment.

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Inventories

3 Months Ended

Mar. 31, 2012

Inventories [Abstract]

Inventories

4.INVENTORIES

Inventories are carried at the lower of cost or market, except grain held for sale, which is valued at market value. During the three months ended March 31, 2012, the Company recorded a $0.8 million lower of cost or market adjustment in cost of goods sold within the ethanol production segment. The components of inventories are as follows (in thousands):

	March 31,		December 31,
	2012		2011
Finished goods	$	83,655	$	57,882
Grain held for sale		95,236		112,948
Raw materials		29,810		23,215
Petroleum & agronomy items held for sale		18,860		14,206
Work-in-process		13,447		11,418
Supplies and parts		9,917		9,401
	$	250,925	$	229,070

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Related Party Transactions

3 Months Ended

Mar. 31, 2012

Related Party Transactions [Abstract]

Related Party Transactions

13.RELATED PARTY TRANSACTIONS

Short-Term Note Payable

On March 9, 2012, the Company repurchased 3.7 million shares of its Common Stock from a subsidiary of NTR plc, which was previously the largest shareholder of the Company, for $37.2 million. The Company paid $10.1 million in cash and issued a secured note bearing 5% interest per annum for $27.2 million that is due on March 9, 2013. The $27.2 million note is secured by the shares repurchased and the Company’s interest in Green Plains Shenandoah LLC. At March 31, 2012, $27.2 million was outstanding on the note payable.

Commercial Contracts

Three subsidiaries of the Company have executed separate financing agreements for equipment with AXIS Capital Inc. Gordon F. Glade, President and Chief Executive Officer of AXIS Capital is a member of our Board of Directors. Totals of $0.3 million and $0.5 million were included in debt at March 31, 2012 and December 31, 2011, respectively, under these financing arrangements. Payments, including principal and interest, totaled $0.2 million and $0.2 million during the three months ended March 31, 2012 and 2011, respectively. The highest amount outstanding during the three months ended March 31, 2012 was $0.4 million, and the weighted average interest rate for all financing agreements with AXIS Capital was 6.1%.

The Company has entered into ethanol purchase, sale and throughput agreements with Center Oil Company. Gary R. Parker, President and Chief Executive Officer of Center Oil, is a member of our Board of Directors. During the three months ended March 31, 2012 and 2011, cash receipts from Center Oil totaled $2.2 million and $43.1 million, respectively and cash payments to Center Oil totaled $1.0 million and $1.0 million for the same periods, respectively, on these contracts. In October 2011, the Company also entered into an operating lease agreement with Center Oil in which the Company will pay $42 thousand per month for the lease of 35 railcars. The agreement is effective through September 30, 2013. The Company had no outstanding receivables from Center Oil at March 31, 2012 and $1.0 million included in outstanding receivables from Center Oil at December 31, 2011. The Company had no outstanding payables at March 31, 2012 and $69 thousand in outstanding payables at December 31, 2011 under these purchase and sale agreements.

Aircraft Lease

The Company has entered into an agreement with Hoovestol Inc. for the lease of an aircraft. Wayne B. Hoovestol, President of Hoovestol Inc., is Chairman of our Board of Directors. The Company has agreed to pay $6,667 per month for use of up to 100 hours per year of the aircraft. Any flight time in excess of 100 hours per year will incur additional hourly-based charges. During the three months ended March 31, 2012 and 2011, payments related to this agreement totaled $33 thousand and $20 thousand, respectively. The Company did not have any receivables from or payables to Hoovestol Inc. at March 31, 2012 and December 31, 2011.

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Earnings Per Share

3 Months Ended

Mar. 31, 2012

Earnings Per Share [Abstract]

Earnings Per Share

9.EARNINGS PER SHARE

Basic earnings per common shares, or EPS, is calculated by dividing net income available to common stockholders by the weighted average number of common shares outstanding during the period. Diluted EPS is computed by dividing net income on an as-if-converted basis available to common stockholders by the weighted average number of common shares outstanding during the period, adjusted for the dilutive effect of any outstanding dilutive securities. Adjusting net income to net income on an as-if-converted basis and adjusting the weighted average number of common shares outstanding for the effect of any outstanding dilutive securities is antidilutive when a net loss has been realized. The reconciliations of net income to net income on an as-if-converted basis and basic and diluted earnings per share are as follows (in thousands):

		Three Months Ended
		March 31,
		2012		2011
Net income (loss) attributable to Green Plains		$	(12,692)	$	7,741
Weighted average shares outstanding - basic			32,238		36,199
	Income (loss) attributable to Green Plains stockholders - basic	$	(0.39)	$	0.21
Net income (loss) attributable to Green Plains		$	(12,692)	$	7,741
Interest and amortization on convertible debt			-		1,440
Tax effect of interest on convertible debt			-		(518)
Net income (loss) attributable to Green Plains on an as-if-converted basis		$	(12,692)	$	8,663
Weighted average shares outstanding - basic			32,238		36,199
Effect of dilutive convertible debt			-		6,280
Effect of dilutive stock-based compensation awards			-		285
	Total potential shares outstanding		32,238		42,764
	Income (loss) attributable to Green Plains stockholders - diluted	$	(0.39)	$	0.20

Excluded from the computations of diluted EPS were stock-based compensation awards totaling 0.8 million and 0.7 million shares for the three months ended March 31, 2012 and 2011, respectively, because the exercise prices or the grant-date fair value, as applicable, of the corresponding awards were greater than the average market price of the Company’s common stock during the respective periods. For the three months ended March 31, 2012, 0.3 million shares related to stock-based compensation awards and 6.3 million shares related to convertible debt were also excluded from the computation of diluted EPS as the inclusion of these shares would have been antidilutive. As consideration for the acquisition of the Lakota and Riga ethanol plants in October 2010, the Company issued warrants for 700,000 shares of its stock at a price of $14.00 per share. The warrants are excluded from the computations of diluted EPS as the exercise price is greater than the average market price of the Company’s common stock for the three months ended March 31, 2012.

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Derivative Financial Instruments

3 Months Ended

Mar. 31, 2012

Derivative Financial Instruments [Abstract]

Derivative Financial Instruments

6.DERIVATIVE FINANCIAL INSTRUMENTS

At March 31, 2012, the Company’s consolidated balance sheet reflects deferred losses, net of tax, of $0.3 million in accumulated other comprehensive loss. The Company expects all of the deferred losses at March 31, 2012 will be reclassified into income over the next 12 months as a result of hedged transactions that are forecasted to occur. The amount ultimately realized in income, however, will differ as commodity prices change.

Fair Values of Derivative Instruments

The following table provides information about the fair values of our derivative financial instruments and the line items in the consolidated balance sheets in which the fair values are reflected:

		Asset Derivatives'						Liability Derivatives'
		Fair Value						Fair Value
Derivative Instruments		March 31,			December 31,			March 31,		December 31,
Consolidated Balance Sheet Location		2012			2011			2012		2011
	Derivative financial instruments (1)	$	5,508	(2)	$	19,022	(3)	$	-	$	-
	Accrued and other liabilities		-			-			7,271		5,280
	Other liabilities		-			-			115		137
	Total	$	5,508		$	19,022		$	7,386	$	5,417
(1) Derivative financial instruments as reflected on the balance sheet include a margin deposit asset of $22.8 million and a margin deposit
	liability of $1.6 million at March 31, 2012 and December 31, 2011, respectively.
(2) Balance at March 31, 2012, includes $0.1 million and $1.2 million of net deferred losses on derivative financial instruments
	designated as cash flow hedging instruments and fair value hedging instruments, respectively.
(3) Balance at December 31, 2011, includes $12.2 million of net deferred gains on derivative financial instruments designated as
	cash flow hedging instruments.

Refer to Note 2 - Fair Value Disclosures, which also contains fair value information related to derivative financial instruments.

Effect of Derivative Instruments on Consolidated Statements of Operations and Consolidated Statements of Stockholders’ Equity and Comprehensive Income

The following tables provide information about the gain or loss recognized in income and other comprehensive income on our derivative financial instruments and the line items in the financial statements in which such gains and losses are reflected:

Gains (Losses) on Derivative Instruments Not Designated in a Hedging Relationship	Three Months Ended March 31,
Consolidated Statements of Operations Location	2012		2011
Revenue	$	(2,885)	$	615
Cost of goods sold		1,185		(25,240)
Net decrease recognized in earnings	$	(1,700)	$	(24,625)

Locations of Gain (Loss) Due to Ineffectiveness of Cash Flow Hedges	Three Months Ended March 31,
Consolidated Statements of Operations Location	2012		2011
Revenue	$	5	$	(118)
Cost of goods sold		(64)		20
Net decrease recognized in earnings	$	(59)	$	(98)

Location of Gains (Losses) Reclassified from Accumulated Other Comprehensive Income (Loss) into Net Income (Loss)	Three Months Ended March 31,
Consolidated Statements of Operations Location	2012		2011
Revenue	$	617	$	(4,457)
Cost of goods sold		(4,698)		3,544
Net decrease recognized in earnings	$	(4,081)	$	(913)

	Effective Portion of Cash Flow Hedges Recognized in	Three Months Ended March 31,
Other Comprehensive Income (Loss)		2012		2011
Commodity Contracts		$	68	$	(7,553)

Locations of Gain (Loss) from Fair Value Hedges of Ethanol Inventory	Three Months Ended March 31,
Consolidated Statements of Operations Location	2012		2011
Revenue (effect of change in inventory value)	$	1,218	$	-
Revenue (effect of fair value hedge)		(1,218)		-
Ineffectiveness recognized in earnings	$	-	$	-

There were no gains or losses due to the discontinuance of cash flow hedge treatment during the three months ended March 31, 2012.

The table below summarizes the volumes of open commodity derivative positions as of March 31, 2012 (in thousands):

March 31, 2012
	Exchange Traded		Non-Exchange Traded
Derivative Instruments	Net Long & (Short) (1)		Long (2)	(Short) (2)	Unit of Measure	Commodity
Futures	(17,211)				Bushels	Corn, Soybeans and Wheat
Futures	14,425	(3)			Bushels	Corn
Futures	(41,531)				Gallons	Ethanol
Futures	(53,844)	(3)			Gallons	Ethanol
Futures	(8,400)	(4)			Gallons	Ethanol
Options	4,797				Bushels	Corn
Options	1,754				Gallons	Ethanol
Forwards			19,030	(7,817)	Bushels	Corn, Soybeans, Wheat and Milo
Forwards			144,780	(235,765)	Gallons	Ethanol
Forwards			16	(125)	Tons	Distillers Grains
(1) Exchange traded futures and options are presented on a net long and (short) position basis. Options are presented on a delta-
adjusted basis.
(2) Non-exchange traded forwards are presented on a gross long and (short) position basis.
(3) Futures used for cash flow hedges.
(4) Futures used for fair value hedges.

Energy trading contracts that do not involve physical delivery are presented net in revenues on the consolidated statements of operations. Revenues and cost of goods sold under such contracts are summarized in the table below for the periods indicated (in thousands):

	Three Months Ended March 31,
	2012		2011
Revenue	$	6,575	$	11,274
Cost of goods sold	$	6,485	$	10,872

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Stock-Based Compensation

3 Months Ended

Mar. 31, 2012

Stock-Based Compensation [Abstract]

Stock-Based Compensation

8.STOCK-BASED COMPENSATION

The Company has equity incentive plans which reserve a combined total of 3.5 million shares of common stock for issuance pursuant to their terms. The plans provide for the granting of shares of stock, including options to purchase shares of common stock, stock appreciation rights tied to the value of common stock, non-vested stock and non-vested stock unit awards to eligible employees, non-employee directors and consultants. The Company measures share-based compensation grants at fair value on the grant date, adjusted for estimated forfeitures. The Company records noncash compensation expense related to equity awards in its financial statements over the requisite service period on a straight-line basis. All of the Company’s existing share-based compensation awards have been determined to be equity awards.

A summary of stock option activity for the three months ended March 31, 2012 is as follows:

		Shares	Weighted-Average Exercise Price		Weighted-Average Remaining Contractual Term (in years)	Aggregate Intrinsic Value (in thousands)
Outstanding at December 31, 2011		1,122,499	$	15.68	3.8	$	1,374
	Granted	-		-
	Exercised	(16,332)		8.71			45
	Forfeited	-		-
	Expired	-		-
Outstanding at March 31, 2012		1,106,167	$	15.78	3.6	$	1,865
Exercisable at March 31, 2012 (1)		1,045,167	$	16.00	3.3	$	1,832
	(1) Includes in-the-money options totaling 518,667 shares at a weighted-average exercise price of $7.26.

The Company’s option awards allow employees to exercise options through cash payment to the Company for the shares of common stock or through a simultaneous broker-assisted cashless exercise of a share option, through which the employee authorizes the exercise of an option and the immediate sale of the option shares in the open market. The Company uses newly-issued shares of common stock to satisfy its share-based payment obligations.

The following table summarizes non-vested stock award and deferred stock unit, or DSU, activity for the three months ended March 31, 2012:

		Non-Vested Shares and DSU's	Weighted-Average Grant-Date Fair Value		Weighted-Average Remaining Vesting Term (in years)
Nonvested at December 31, 2011		486,012	$	11.81
	Granted	453,859		11.20
	Forfeited	-		-
	Vested	(269,070)		11.93
Nonvested at March 31, 2012		670,801	$	11.35	2.3

Compensation costs expensed for share-based payment plans described above were approximately $2.2 million and $1.7 million during the three months ended March 31, 2012 and 2011, respectively. At March 31, 2012, there were $6.9 million of unrecognized compensation costs from share-based compensation arrangements, which is related to non-vested awards. This compensation is expected to be recognized over a weighted-average period of approximately 2.2 years. The potential tax benefit realizable for the anticipated tax deductions of the exercise of share-based payment arrangements generally would approximate 38% of these expense amounts.

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Stockholders Equity

3 Months Ended

Mar. 31, 2012

Stockholders Equity [Abstract]

Stockholders Equity

10.STOCKHOLDERS’ EQUITY

Components of stockholders’ equity are as follows (in thousands):

										Accum.
										Other					Total
						Additional				Comp					Green Plains		Non-		Total
			Common Stock			Paid-in		Retained		Income		Treasury Stock			Stockholders'		Controlling		Stockholders'
			Shares	Amount		Capital		Earnings		(Loss)		Shares	Amount		Equity		Interest		Equity
Balance, December 31, 2011			36,414	$	36	$	440,469	$	95,761	$	(2,953)	3,500	$	(28,201)	$	505,112	$	245	$	505,357
Net loss			-		-		-		(12,692)		-	-		-		(12,692)		(4)		(12,696)
	Unrealized gain on derivatives,
		net of tax effect of $1,516	-		-		-		-		2,633	-		-		2,633		-		2,633
	Repurchase of common stock		-		-		-		-		-	3,700		(37,607)		(37,607)		-		(37,607)
	Stock-based compensation		360		1		1,170		-		-	-		-		1,171		-		1,171
	Stock options exercised		16		-		142		-		-	-		-		142		-		142
Balance, March 31, 2012			36,790	$	37	$	441,781	$	83,069	$	(320)	7,200	$	(65,808)	$	458,759	$	241	$	459,000

On March 9, 2012, the Company repurchased 3.7 million shares of its common stock for $37.2 million. Shares of common stock repurchased by the Company are recorded at cost as treasury stock and result in a reduction of stockholders’ equity in the accompanying consolidated balance sheets. When shares are reissued, the Company will use the weighted average cost method for determining the cost basis. The difference between the cost of the shares and the issuance price will be added or deducted from additional paid-in capital. The Company does not have a share repurchase program and does not intend to retire the repurchased shares.

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Consolidated Statements Of Comprehensive Income (USD $) In Thousands, unless otherwise specified	3 Months Ended
	Mar. 31, 2012	Mar. 31, 2011
Consolidated Statements Of Comprehensive Income (Loss) [Abstract]
Net income	$ (12,696)	$ 7,531
Other comprehensive income, net of tax
Unrealized gains (losses) on derivatives arising during period, net of tax (expense) benefit of $(25) and $2,964, respectively	43	(4,589)
Reclassification of realized losses on derivatives included in net income (loss), net of tax benefit of $1,491 and $364 respectively	2,590	549
Other comprehensive income (loss)	2,633	(4,040)
Total comprehensive income	(10,063)	3,491
Comprehensive loss attributable to noncontrolling interests	4	210
Other Comprehensive Income (Loss), before Tax, Portion Attributable to Parent	$ (10,059)	$ 3,701

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Segment Information

3 Months Ended

Mar. 31, 2012

Segment Information [Abstract]

Segment Information

3.SEGMENT INFORMATION

Company management reviews financial and operating performance in the following four separate operating segments: (1) production of ethanol and distillers grains, collectively referred to as ethanol production, (2) corn oil production, (3) grain warehousing and marketing, as well as sales and related services of agronomy and petroleum products, collectively referred to as agribusiness, and (4) marketing and distribution of Company-produced and third-party ethanol, distillers grains and corn oil, collectively referred to as marketing and distribution. Selling, general and administrative expenses, primarily consisting of compensation of corporate employees, professional fees and overhead costs not directly related to a specific operating segment, are reflected in the table below as corporate activities.

During the normal course of business, the Company enters into transactions between segments. Examples of these intersegment transactions include, but are not limited to, the ethanol production segment selling ethanol to the marketing and distribution segment and the agribusiness segment selling grain to the ethanol production segment. These intersegment activities are recorded by each segment at prices approximating market and treated as if they are third-party transactions. Consequently, these transactions impact segment performance. However, revenues and corresponding costs are eliminated in consolidation and do not impact the Company’s consolidated results.

The following are certain financial data for the Company’s operating segments for the periods indicated (in thousands):

				Three Months Ended March 31,
				2012		2011
Revenues:
	Ethanol production
		Revenues from external customers		$	45,358	$	35,119
		Intersegment revenues			412,819		432,684
			Total segment revenues		458,177		467,803
	Corn oil production
		Revenues from external customers			508		1,071
		Intersegment revenues			13,011		3,251
			Total segment revenues		13,519		4,322
	Agribusiness
		Revenues from external customers			72,825		63,854
		Intersegment revenues			45,402		50,264
			Total segment revenues		118,227		114,118
	Marketing and distribution
		Revenues from external customers			656,704		712,283
		Intersegment revenues			67		112
			Total segment revenues		656,771		712,395
	Revenues including intersegment activity				1,246,694		1,298,638
	Intersegment eliminations				(471,299)		(486,311)
	Revenues as reported			$	775,395	$	812,327

		Three Months Ended March 31,
		2012		2011
Gross profit (loss):
	Ethanol production	$	(10,035)	$	23,314
	Corn oil production		7,936		2,091
	Agribusiness		6,246		6,016
	Marketing and distribution		4,186		6,674
	Intersegment eliminations		437		(471)
		$	8,770	$	37,624
Operating income (loss):
	Ethanol production	$	(13,880)	$	19,535
	Corn oil production		7,848		2,069
	Agribusiness		669		972
	Marketing and distribution		510		2,639
	Intersegment eliminations		471		(456)
	Corporate activities		(6,709)		(4,763)
		$	(11,091)	$	19,996

The following table sets forth revenues by product line for the periods indicated (in thousands):

		Three Months Ended March 31,
		2012		2011
Revenues:
	Ethanol	$	583,535	$	654,484
	Corn oil		13,155		4,322
	Distillers grains		100,604		87,274
	Grain		64,219		55,287
	Agronomy products		7,118		7,457
	Other		6,764		3,503
		$	775,395	$	812,327

The following are total assets for our operating segments for the periods indicated (in thousands):

	March 31,		December 31,
	2012		2011
Total assets:
Ethanol production	$	876,160	$	879,500
Corn oil production		26,916		24,601
Agribusiness		225,925		233,201
Marketing and distribution		189,425		181,466
Corporate assets		105,583		121,429
Intersegement eliminations		(20,323)		(19,369)
	$	1,403,686	$	1,420,828