Filed Pursuant to Rule 424(B)(3)
Registration Statement No. 333-132881

PROSPECTUS SUPPLEMENT No. 1
(To Prospectus dated May 8, 2007)

Aventine Renewable Energy Holdings, Inc.
20,881,025 Shares of Common Stock

RECENT DEVELOPMENTS

We have attached to this prospectus supplement, and incorporated by reference into it, our Quarterly Report on Form 10-Q for the period ended March 31, 2007 filed with the Securities and Exchange Commission on May 9, 2007.

The date of this prospectus supplement is May 9, 2007.

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D.C. 20549

FORM 10-Q

x Quarterly report pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934

For the quarterly period ended March 31, 2007

o Transition report pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934

For the transition period from to .

COMMISSION FILE NUMBER 001-32922

AVENTINE RENEWABLE ENERGY HOLDINGS, INC.

(Exact name of registrant as specified in its charter)

Delaware		05-0569368
(State of Incorporation)		(IRS Employer Identification No.)

1300 South 2nd Street
Pekin, Illinois		61554
(Address of Principal Executive Offices)		(Zip Code)

(309) 347-9200

(Registrant’s Telephone Number, including Area Code)

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

Indicate by checkmark whether the registrant is a large accelerated filer, an accelerated filer, or a non-accelerated filer. See definition of “accelerated filer and large accelerated filer” in Rule 12b-2 of the Exchange Act. (Check one):

Large accelerated filer o

Accelerated o

Non-accelerated filer x

Indicate by checkmark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). YES o NO x

Indicate the number of shares outstanding of each class of Common Stock, as of the latest practicable date

Class		Outstanding as of May 9, 2007
Common Stock, $0.001 Par Value		41,910,744 Shares

FORM 10-Q

QUARTERLY REPORT

TABLE OF CONTENTS

		Page No.
	PART I
Item 1.	Financial Statements
	Condensed Consolidated Statements of Operations (Unaudited) — Three-month periods ended March 31, 2007 and 2006	1
	Condensed Consolidated Balance Sheets — March 31, 2007 (Unaudited) and December 31, 2006	2
	Condensed Consolidated Statements of Cash Flows (Unaudited) — Three-months ended March 31, 2007 and 2006	3
	Notes to Unaudited Condensed Consolidated Financial Statements	4

Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	16

Item 3.	Quantitative and Qualitative Disclosures About Market Risk	25

Item 4.	Controls and Procedures	27

	PART II

Item 1.	Legal Proceedings	27

Item 1A.	Risk Factors	27

Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	28

Item 3.	Default Upon Senior Securities	28

Item 4.	Submission of Matters to a Vote of Security Holders	28

Item 5.	Other Information	28

Item 6.	Exhibits	28

PART I. FINANCIAL INFORMATION

Item 1. Financial Statements

Aventine Renewable Energy Holdings, Inc. and Subsidiaries
Condensed Consolidated Statements of Operations
(Unaudited)

	Three Months Ended March 31,
(In thousands except per share amounts)	2007			2006
Net sales	$	436,662		$	313,520
Cost of goods sold	408,247			282,925
Gross profit	28,415			30,595
Selling, general and administrative expenses	9,598			6,266
Other (income)	(164		)	(265		)
Operating income	18,981			24,594
Other income (expense):
Interest income	1,368			655
Interest expense	(336		)	(4,365		)
Other non-operating income (expense)	3,869			555
Minority interest	(518		)	(1,266		)
Income before income taxes	23,364			20,173
Income tax expense	8,424			7,986
Net income	$	14,940		$	12,187

Per share data:
Income per common share — basic:	$	0.36		$	0.35
Basic weighted average number of common shares	41,811			34,684

Income per common share — diluted:	$	0.35		$	0.34
Diluted weighted average number of common and common equivalent shares	42,458			36,019

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

Aventine Renewable Energy Holdings, Inc. and Subsidiaries
Condensed Consolidated Balance Sheets

(In thousands except share amounts)	March 31, 2007 (Unaudited)			December 31, 2006
Assets
Current assets
Cash and cash equivalents	$	281,120		$	29,791
Short-term investments	144,750			98,925
Accounts receivable	58,175			79,729
Inventories	93,659			67,051
Income tax receivable	1,044			6,446
Prepaid expenses and other	7,611			4,549
Total current assets	586,359			286,491
Property, plant and equipment, net	125,112			115,645
Net deferred tax assets	2,415			—
Other assets	14,070			6,000
Total assets	$	727,956		$	408,136
Liabilities and Stockholders’ Equity
Current liabilities
Accounts payable	$	76,423		$	77,442
Accrued liabilities	2,900			3,679
Other current liabilities	4,198			2,123
Total current liabilities	83,521			83,244
Senior unsecured 10% notes due April 2017	300,000			—
Minority interest	10,307			10,221
Net deferred taxes liabilities	—			6,104
Other long-term liabilities	13,065			4,404
Total liabilities	406,893			103,973
Stockholders’ equity
Common stock, par value $0.001 per share; 185,000,000 shares authorized; 41,900,744 and 41,782,276 shares issued and outstanding as of March 31, 2007 and December 31, 2006, respectively, net of 21,229,025 shares held in treasury as of March 31, 2007 and December 31, 2006	42			42
Preferred stock, 50,000,000 shares authorized, no shares issued or outstanding	—			—
Additional paid-in capital	276,019			274,307
Retained earnings	46,076			30,888
Accumulated other comprehensive loss	(1,074		)	(1,074		)
Total stockholders’ equity	321,063			304,163
Total liabilities and stockholders’ equity	$	727,956		$	408,136

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

Aventine Renewable Energy Holdings, Inc. and Subsidiaries
Condensed Consolidated Statements of Cash Flows
(Unaudited)

	Three Months Ended March 31,
(In thousands)	2007			2006
Operating Activities
Net income	$	14,940		$	12,187
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	2,950			1,380
Minority interest	518			1,266
Stock-based compensation expense	1,594			1,308
Deferred income tax	645			(155		)
Other	248			(195		)
Changes in operating assets and liabilities:
Accounts receivable, net	26,957			5,035
Inventories	(26,608		)	(16,407		)
Accounts payable and other liabilities	(419		)	(1,062		)
Other changes in operating assets and liabilities	(2,870		)	4,715
Net cash provided by operating activities	17,955			8,072

Investing Activities
Additions to property, plant and equipment, net	(12,418		)	(13,016		)
Investment in short-term securities	(45,825		)	—
Increase in restricted cash for investing activities	—			(597		)
Use of restricted cash for plant expansion	—			13,674
Net cash provided by (used for) investing activities	(58,243		)	61

Financing Activities
Proceeds from issuance of senior unsecured notes	300,000			—
Payment of debt issuance costs	(8,070		)	—
Proceeds from stock option exercises	173			—
Tax benefit of stock option exercises	(54		)	—
Net repayments on revolving credit facilities	—			(1,514		)
Distributions to minority shareholders	(432		)	(216		)
Net cash provided by (used for) financing activities	291,617			(1,730		)
Net increase in cash and cash equivalents	251,329			6,403
Cash and cash equivalents at beginning of period	29,791			3,750
Cash and cash equivalents at end of period	$	281,120		$	10,153

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

Aventine Renewable Energy Holdings, Inc. and Subsidiaries
Notes to Unaudited Condensed Consolidated Financial Statements

(1) Basis of Reporting for Interim Financial Statements

The accompanying unaudited condensed consolidated financial statements include the accounts of Aventine Renewable Energy Holdings, Inc. and its subsidiaries, which are collectively referred to as “Aventine”, the “Company”, “we”, “our” or “us”, unless the context otherwise requires. All significant intercompany transactions have been eliminated in consolidation.

We have prepared the unaudited condensed consolidated financial statements included herein pursuant to the rules and regulations of the Securities and Exchange Commission. Certain information and footnote disclosures normally included in statements prepared in accordance with generally accepted accounting principles have been omitted pursuant to such rules and regulations, although we believe that the disclosures are adequate to make the information presented not misleading. These financial statements should be read in conjunction with the financial statements and notes thereto included in our Annual Report on Form 10-K for the year ended December 31, 2006.

The accompanying condensed consolidated financial statements presented herewith reflect all adjustments (consisting of only normal and recurring adjustments) which, in the opinion of management, are necessary for a fair presentation of the results of operations for the three month periods ended March 31, 2007 and 2006. The results of operations for interim periods are not necessarily indicative of results to be expected for an entire year.

The preparation of financial statements in conformity with accounting principles generally accepted in the United States requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ materially from those estimates.

As of March 31, 2007, the Company’s Summary of Critical Accounting Policies for the year ended December 31, 2006, which are detailed in the Company’s Annual Report on Form 10-K, have not changed from December 31, 2006, except for the adoption of Financial Accounting Standards Board (“FASB”) Interpretation No. 48 (“FIN 48”), Accounting for Uncertainty in Income Taxes. See Note 12 for additional information regarding the adoption of FIN 48 by the Company.

(2) Recent Accounting Pronouncements

In September 2006, the FASB issued Statement of Financial Accounting Standards No. 157 (“SFAS 157”), Fair Value Measurements. SFAS 157 defines fair value, establishes a framework for measuring fair value, and expands disclosure about fair value measurements. The statement is effective for financial statements issued for fiscal years beginning after November 15, 2007. The Company is currently evaluating the effect that the adoption of SFAS 157 will have, if any, on its consolidated results of operations, financial position and related disclosures.

In February 2007, The FASB issued Statement of Financial Accounting Standards No. 159 (“SFAS 159”), The Fair Value Option for Financial Assets and Financial Liabilities Including an amendment of FASB Statement No. 115. SFAS No. 159 permits a company to choose to measure many financial instruments and other items at fair value that are not currently required to be measured at fair value. The objective is to improve financial reporting by providing a company with the opportunity to

mitigate volatility in reported earnings caused by measuring related assets and liabilities differently without having to apply complex hedge accounting provisions. A company shall report unrealized gains and losses on items for which the fair value option has been elected in earnings at each subsequent reporting date. SFAS No. 159 will be effective for fiscal years that begin after November 15, 2007. We are currently assessing the impact SFAS No. 159 will have on our consolidated financial statements.

(3) Short-Term Securities

We from time to time invest a portion of our cash in tax-free municipal auction rate certificates which generally have contractual maturities of greater than 20 years. We consider these certificates as held for sale. These certificates are widely traded in the public markets and may be sold as needed. The interest rates on these certificates reprice every 35 days to the then current market rate. Generally, the carrying value of these securities approximates the market value, and there is no gain or loss expected from changes in market value.

(4) Inventories

Inventories are as follows:

(In thousands)	March 31, 2007		December 31, 2006
Finished products	$	85,668	$	61,775
Work-in-process	2,327		1,106
Raw materials	2,972		2,070
Supplies	2,692		2,100
Totals	$	93,659	$	67,051

(5) Prepaid Expenses and Other

Prepaid expenses and other are as follows:

(In thousands)	March 31, 2007		December 31, 2006
Fair value of derivative instruments	$	4,483	$	1,503
Prepaid insurance	1,339		1,280
Deferred income taxes current	1,032		1,064
Other prepaid expenses	757		702
Totals	$	7,611	$	4,549

(6) Other Assets

Other assets are as follows:

(In thousands)	March 31, 2007		December 31, 2006
Deferred debt issuance costs	$	8,070	$	—
Investment in marketing alliances	6,000		6,000
Totals	$	14,070	$	6,000

Deferred debt issuance costs are subject to amortization. Deferred debt issuance costs of $7.2 million related to our 10% senior unsecured notes will be amortized utilizing a method which approximates the effective interest method over the remaining life of 10 years, resulting in amortization expense of $0.5 million for 2007, and $0.7 million yearly thereafter. Deferred debt issuance costs of $0.9 million related to our secured revolving credit facility will be amortized utilizing a method which approximates the effective interest method over the five year remaining life, resulting in amortization expense of $0.1 million in 2007, and $0.2 million in each of the next four succeeding years beginning in 2008.

(7) Debt

The following table summarizes long-term debt:

(In thousands)	March 31, 2007		December 31, 2006
Senior unsecured 10% notes due April 2017	$	300,000	$	—
Secured revolving credit facility	—		—
	300,000		—
Less short-term borrowings	—		—
Total	$	300,000	$	—

Liquidity Facility

On March 23, 2007, we replaced our previous $30 million liquidity facility with a new $200 million liquidity facility. Our new liquidity facility consists of a secured revolving credit facility with JPMorgan Chase Bank, N.A. of up to $200 million, subject to collateral availability, which, under certain circumstances, can be increased up to $300 million. We had no borrowings outstanding under our secured revolving credit facility at March 31, 2007, and $1.2 million of standby letters of credit outstanding, leaving approximately $88.7 million in additional borrowing availability under our secured revolving credit facility as of that date. As of December 31, 2006, we had no borrowings outstanding under our previous secured revolving credit facility and $4.0 million of standby letters of credit outstanding, leaving approximately $26.0 million in additional borrowing availability under the previous secured revolving credit facility as of that date.

A fixed asset component in an amount of $50 million may be added to the borrowing base on or prior to December 31, 2007 upon the satisfaction of certain requirements. We are in the process of satisfying the requirements necessary in order to take advantage of this fixed asset component.

Senior Notes

In March 2007, we issued $300 million aggregate principal amount of senior unsecured 10% fixed-rate notes due 2017 (“Notes”). Our Notes were issued pursuant to an indenture, dated as of March 27, 2007, between us and Wells Fargo Bank, N.A., as trustee. The Notes are general unsecured obligations of the Company and certain of its guarantor subsidiaries, initially limited to $300 million aggregate principal amount. We may, subject to the covenants and applicable law, issue additional notes under the indenture. Any additional Notes would be treated as a single class with the previously issued Notes for all purposes under the indenture.

Our Notes have interest payments due semi-annually on April 1 and October 1 of each year, and are redeemable after the dates and at prices (expressed in percentages of principal amount on the redemption date), as set forth below:

Year	Percentage
April 1, 2012	105.000	%
April 1, 2013	103.330	%
April 1, 2014	101.667	%
April 1, 2015 and thereafter	100.000	%

In addition, at any time prior to April 1, 2010, we may redeem up to 35% of the principal amount of the Notes from time to time originally issued with the net cash proceeds of one or more sales of qualifying capital stock of the Company at a redemption price of 100% of the principal amount, together with accrued and unpaid interest to the redemption date, provided that at least 65% of the aggregate principal amount of the Notes originally issued remains outstanding immediately after such redemption and notice of any such redemption is mailed within 60 days of each such sale of capital stock.

We have agreed to register the Notes through a shelf registration statement in accordance with a registration rights agreement, and upon the shelf registration statement being declared effective, to exchange the Notes for an issue of unsubordinated notes, with terms identical to the Notes. If by October 23, 2007 we have not consummated a registered exchange offer for the Notes or caused a shelf registration statement with respect to resale of the Notes to be declared effective, the annual interest rate on the Notes will increase by 0.25% and by 0.25% for each subsequent 90 day period, up to a maximum 1.00% over the stated fixed rate of the Notes.

(8) Other Long-Term Liabilities

Other long-term liabilities are as follows:

(In thousands)	March 31, 2007		December 31, 2006
Reserve for uncertain tax positions (See Note 12)	$	8,503	$	—
Accrued interest on Uncertain tax positions (See Note 12)	627		—
Accrued pension and postretirement	2,063		2,427
Unearned commissions	1,872		1,977
Totals	$	13,065	$	4,404

(9) Stock-Based Compensation Plans

The Company values its share-based payment awards using the Black-Scholes option-pricing model (“Black-Scholes model”). The determination of fair value of share-based payment awards on the date of grant using the Black-Scholes model is affected by our stock price as well as the input of other subjective assumptions. The option-pricing model requires a number of assumptions, of which the most significant are, expected stock price volatility, the expected pre-vesting forfeiture rate and the expected option term (the amount of time from the grant date until the options are exercised or expire). Expected volatility is normally calculated based upon actual historical stock price movements over the expected option term. Since we have no long-term history of stock price volatility as a public company, we calculate volatility by considering, among other things, the expected volatilities of public companies engaged in similar industries. Pre-vesting forfeitures are estimated using a 3% forfeiture rate. The expected option term is calculated using the “simplified” method permitted by SAB 107. Our options have characteristics significantly different from those of traded options, and changes in the assumptions can materially affect the fair value estimates.

Pre-tax stock-based compensation expense for the three month periods ended March 31, 2007 and 2006 was approximately $1.6 million and $1.3 million, respectively, all of which was charged to selling, general and administrative expense. This expense reduced earnings per share by $0.02 per basic and diluted share for each of the quarters ended March 31, 2007 and 2006. The Company recognized a tax benefit on its condensed consolidated statement of income from stock-based compensation expense in the amount of $0.6 million and $0.5 million for the three month periods ended March 31, 2007 and 2006, respectively. The Company recorded pre-tax stock-based compensation expense for the three month periods ended March 31, 2007 and 2006 as follows:

	Three Months Ended March 31,
(in millions)	2007		2006
Stock-based compensation expense:
Non-qualified stock options	$	1.5	$	1.3
Restricted stock	$	0.1	$	—
Restricted stock units	$	—	$	—

As of March 31, 2007 and 2006, the Company had not yet recognized compensation expense on the following non-vested awards:

	2007			2006
(in millions)	Non-recognized Compensation		Weighted Average Remaining Recognition Period (years)	Non-recognized Compensation		Weighted Average Remaining Recognition Period (years)
Non-qualified options	$	21.0	5.9	$	15.9	5.0
Restricted stock	1.2		4.7	—		—
Restricted stock units	0.2		1.7	—		—
Total	$	22.4	5.8	$	15.9	5.0

The Company granted stock options during the quarter ended March 31, 2007. The Company did not grant any stock options in the quarter ended March 31, 2006. The determination of the fair value of the stock option awards, using the Black-Scholes model, incorporated the assumptions in the following table for stock options granted during the three month period ended March 31, 2007. The risk-free rate is based on the U.S. Treasury yield curve in effect at the time of grant over the expected term. Expected volatility is calculated by considering, among other things, the expected volatilities of public companies engaged in similar industries. The expected option term is calculated using the “simplified” method permitted by SAB 107. Assumptions for options granted in the three month period ending March 31, 2007 are as follows:

Expected stock price volatility	58.0		%
Expected life (in years)	6.5
Risk-free interest rate	4.6		%
Expected dividend yield	0.0		%
Weighted average fair value	$	9.27

The following table summarizes stock options outstanding and changes during the three month period ended March 31, 2007:

	Shares (in thousands)	Weighted Average Exercise Price		Weighted Average Remaining Life (years)	Aggregate Intrinsic Value (in thousands)
Options outstanding — January 1, 2007	3,265	$	6.57	8.1	$	—
Granted	200	15.26		9.9	—
Exercised	53	3.27		—	—
Cancelled or expired	—	—		—	—
Options outstanding — March 31, 2007	3,412	$	7.13	7.9	$	37,839
Options exercisable — March 31, 2007	690	$	1.41	7.0	$	11,599

The range of exercise prices of the exercisable options and outstanding options at March 31, 2007 are as follows:

Weighted Average Exercise Price	Number of Exercisable Options	Number of Outstanding Options	Weighted Average Remaining Life (years)
$0.23	429	1,080	6.3
$2.36 - $2.92	157	744	8.2
$4.35	104	718	8.5
$15.26	—	200	9.9
$22.15 - $22.50	—	630	9.0
$43.00	—	40	9.3
Totals	690	3,412	7.9

Restricted stock award activity for the three months ended March 31, 2007 is summarized below:

	Shares (in thousands)	Weighted Average Grant Date Fair Value per Award
Unvested Restricted stock awards — January 1, 2007	8.1	$	27.92
Granted	65.5	15.26
Vested	—	—
Cancelled or expired	—	—
Restricted stock awards — March 31, 2007	73.6	$	16.65

Restricted stock unit award activity for the three months ended March 31, 2007 is summarized below:

	Shares (in thousands)	Weighted Average Grant Date Fair Value per Award
Unvested Restricted stock unit awards — January 1, 2007	—	$	—
Granted	10.6	16.90
Vested	—	—
Cancelled or expired	—	—
Restricted stock unit awards — March 31, 2007	10.6	$	16.90

(10) Interest Expense

The following table summarizes interest expense:

	Three Months Ended March 31,
(in thousands)	2007		2006
Interest expense	$	336	$	4,245
Amortization of deferred debt issuance costs	—		334
Capitalized interest	—		(214		)
Interest expense, net	$	336	$	4,365

(11) Pension Expense

Defined Contribution Plans

We have 401(k) plans covering substantially all of our employees. We recorded expense with respect to these plans for the three month periods ended March 31, 2007 and 2006 of $0.4 million and $0.3 million, respectively. Contributions made under our defined contribution plans include a match, at the Company’s discretion, of employee contributions to the plans.

Qualified Retirement Plan

The Company provides a non-contributory qualified defined benefit pension plan for its unionized employees at our Pekin, IL production facilities. The following table summarizes the components of net periodic pension cost for the qualified pension plan:

	Three Months Ended March 31,
(In thousands)	2007			2006
Service cost	$	88		$	71
Interest cost	124			108
Expected return on plan assets	(180		)	(128		)
Amortization of prior service costs	11			—
Amortization of net actuarial loss	6			12
Net periodic pension cost	$	49		$	63

Postretirement Benefit Obligation

We sponsor a healthcare plan that provides postretirement medical benefits to certain “grandfathered” unionized employees. The plan is contributory, with contributions required at the same rate as active employees. Benefit eligibility under the plan terminates at age 65.

The following table summarizes the components of the net periodic costs for postretirement benefits:

	Three Months Ended March 31,
(In thousands)	2007		2006
Service cost	$	38	$	54
Interest cost	34		44
Amortization of prior service cost	—		15
Net periodic postretirement cost	$	72	$	113

(12) Income Taxes

In July 2006, the FASB issued FIN 48. This interpretation clarified the accounting for uncertainty in income taxes recognized in the financial statements in accordance with FASB Statement No. 109, Accounting for Income Taxes. FIN 48 prescribes a recognition threshold and measurement of a tax position taken or expected to be taken in a tax return. This interpretation also provides guidance on de-recognition, classification, interest and penalties, accounting in interim periods, and disclosure.

We adopted the provisions of FIN 48 on January 1, 2007. As a result of the adoption, we recognized a $0.7 million decrease in our reserves for uncertain tax positions and a $0.5 million increase in accrued interest on uncertain tax positions, resulting in a net $0.2 million increase in retained earnings. We also reclassified $8.1 million between deferred income taxes and other long-term liabilities to conform to the balance sheet presentation requirements of FIN 48.

As of January 1, 2007, we had $8.5 million of uncertain tax benefits. All of our unrecognized tax benefits, if recognized in future periods, would impact the Company’s effective tax rate. For the three months ended March 31, 2007, our liability for unrecognized tax benefits increased by $0.4 million, to $8.9 million.

We include interest expense or income, as well as potential penalties on unrecognized tax benefits, as a component of income tax expense in the condensed consolidated statement of operations. The total amount of accrued interest related to uncertain tax positions at January 1, 2007 was $0.5 million, net of the deferred tax benefit, and is included in other long-term liabilities. For the three months ended March 31, 2007, we increased our accrual for interest related to uncertain tax positions by $0.1 million, net of the deferred tax benefit, to $0.6 million, net of deferred tax benefit, within income tax expense.

Our federal income tax returns for 2003 to 2006 are open tax years. We file in numerous state jurisdictions with varying statutes of limitation open from 2002 through 2006 depending on each jurisdiction’s statute of limitation. In 2006, the IRS commenced an examination of our U.S. income tax return. The Company does not expect this examination to be concluded and settled within the next 12 months, and as such the final outcome is not yet determinable.

Based on the outcome of these examinations, or as a result of the expiration of statute of limitations for specific jurisdictions, our unrecognized tax benefits for tax positions taken on previously filed tax returns may materially change from the unrecognized tax benefits recorded as other long-term liabilities in our financial statements at January 1, 2007. In addition, the outcome of these examinations may impact the valuation of certain deferred tax assets in future periods. As a result, based on the status of these examinations, and the protocol of finalizing audits by the relevant tax authorities, which could include formal legal proceedings, it is not possible to estimate the impact of any amount of such changes, if any, to previously recorded uncertain tax positions.

(13) Earnings Per Share

Basic earnings per share are computed by dividing net income by the weighted average number of common shares outstanding during each period. Diluted earnings per share are calculated using the treasury stock method in accordance with SFAS 128, and includes the effect of all dilutive securities, including non-qualified stock options and restricted stock units (“RSU’s”).

The following table sets forth the computation of basic and diluted earnings per share:

	Three Months Ended March 31,
(In thousands, except per share data)	2007		2006
Net income	$	14,940	$	12,187

Weighted average shares and share equivalents outstanding:
Basic shares	41,811		34,684
Dilutive non-qualified stock options and RSU’s	647		1,335
Diluted weighted average shares and share equivalents	42,458		36,019

Income per common share - basic:	$	0.36	$	0.35
Income per common share - diluted:	$	0.35	$	0.34

We had additional potential dilutive securities outstanding representing 430,000 common shares for the three month period ended March 31, 2007 that were not included in the computation of potentially dilutive securities because the options’ exercise prices were greater than the average market price of the common shares.

(14) Industry Segment

The Company operates in one reportable business segment, the manufacture and marketing of fuel-grade ethanol.

(15) Litigation

Our facilities and operations are subject to extensive environmental laws and regulations, and we are currently involved in various proceedings relating to environmental matters. We are not involved in any legal proceedings that we believe could have a material adverse effect upon our business, operating results or financial condition.

(16) Condensed Consolidating Financial Information

The following tables present condensed consolidating financial information for: (a) Aventine Renewable Energy Holdings, Inc. (the “Parent”) on a stand-alone basis; (b) on a combined basis, the guarantors of the 10% senior unsecured Notes (“Subsidiary Guarantors”), which include Aventine Renewable Energy, LLC; Aventine Renewable Energy, Inc.; Aventine Power, LLC; Aventine Renewable Energy — Aurora West, LLC; and Aventine Renewable Energy — Mt. Vernon, LLC; and (c) the Non-Guarantor Subsidiary, Nebraska Energy, LLC. Each Subsidiary Guarantor is wholly-owned by Aventine Renewable Energy Holdings, Inc. The guarantees of each of the Subsidiary Guarantors are full, unconditional, joint and several. Accordingly, separate financial statements of the wholly-owned Subsidiary Guarantors are not presented because the Subsidiary Guarantors are jointly, severally and unconditionally liable under the guarantees, and the Company believes that separate financial statements and other disclosures regarding the Subsidiary Guarantors are not material to investors. Furthermore, there are no significant legal restrictions on the Parent’s ability to obtain funds from its subsidiaries by dividend or loan.

Aventine Renewable Energy Holdings, Inc. and Subsidiaries
Condensed Consolidating Statements of Operations
For the Three Months Ended March 31, 2007
(Unaudited)

(In thousands)

Parent

Subsidiary
Guarantors

Non-Guarantor
Subsidiary

Eliminations

Consolidated

Net sales

—

439,376

21,923

(24,637

)

436,662

Cost of goods sold

—

413,936

18,698

(24,387

)

408,247

Gross profit

—

25,440

3,225

(250

)

28,415

Selling, general and administrative expenses

163

8,919

766

(250

)

9,598

Other expense (income)

—

(164

)

—

(164

)

Operating income (loss)

(163

)

16,685

2,459

—

18,981

Other income (expense):

Interest income

—

1,342

—

1,368

Interest expense

(120

)

(216

)

—

(336

)

Investment in subsidiaries

23,647

2,447

—

(26,094

)

—

Other non-operating income (expense)

—

3,389

480

—

3,869

Minority interest

—

(518

)

(518

)

Income before income taxes

23,364

23,647

2,965

(26,612

)

23,364

Income tax expense

8,424

9,459

—

(9,459

)

8,424

Net income

14,940

14,188

2,965

(17,153

)

14,940

Aventine Renewable Energy Holdings, Inc. and Subsidiaries
Condensed Consolidating Balance Sheets
March 31, 2007
(Unaudited)

(In thousands)

Parent

Subsidiary
Guarantors

Non-Guarantor
Subsidiary

Eliminations

Consolidated

Assets

Current assets

Cash and cash equivalents

—

277,606

3,514

281,120

Short-term investments

—

144,750

—

144,750

Accounts receivable, net

—

57,690

485

58,175

Inventories

—

91,748

1,911

93,659

Income tax receivable

—

1,044

—

1,044

Other assets

—

6,598

1,013

7,611

Total current assets

—

579,436

6,923

586,359

Property, plant and equipment, net

—

106,277

18,835

125,112

Investment in subsidiaries

758,414

39,838

—

(798,252

)

—

Net deferred tax assets

—

2,415

—

2,415

Other assets

7,131

6,939

—

14,070

Total assets

765,545

734,905

25,758

(798,252

)

727,956

Liabilities and Stockholders’ Equity

Current liabilities

Accounts payable

1,049

71,875

3,499

—

76,423

Accrued liabilities

334

2,344

222

2,900

Other current liabilities

—

4,036

162

4,198

Intercompany balances

143,099

(142,076

)

(1,023

)

—

Total current liabilities

144,482

(63,821

)

2,860

83,521

Long-term debt

300,000

—

300,000

Minority interest

—

10,307

Other long-term liabilities

—

13,065

—

13,065

Total liabilities

444,482

(50,756

)

13,167

406,893

Stockholders’ equity

321,063

785,661

12,591

(798,252

)

321,063

Total liabilities and stockholders’ equity

765,545

734,905

25,758

(798,252

)

727,956

Aventine Renewable Energy Holdings, Inc. and Subsidiaries
Condensed Consolidating Statements of Cash Flows
For the Three Months Ended March 31, 2007
(Unaudited)

(In thousands)

Parent

Subsidiary
Guarantors

Non-Guarantor
Subsidiary

Eliminations

Consolidated

Operating Activities

Net cash provided by (used for) operating activities

(496

)

15,670

2,781

—

17.955

—

Investing Activities

—

Additions to property, plant and equipment

—

(12,340

)

(78

)

—

(12,418

)

Investment in short-term securities

—

(45,825

)

—

(45,825

)

Net cash used for investing activities

—

(58,165

)

(78

)

—

(58,243

)

Financing Activities

Proceeds from issuance of senior unsecured notes

300,000

—

300,000

Payment of debt issuance costs

(8,070

)

—

(8,070

)

Intercompany capital contributions

(291,607

)

292,174

(567

)

—

Proceeds from stock option exercises

173

—

173

Tax benefit of stock option exercises

—

(54

)

—

(54

)

Distribution to minority stockholders

—

1,568

(2,000

)

—

(432

)

Net cash provided by (used for) financing activities

496

293,688

(2,567

)

—

291,617

Net decrease in cash and cash equivalents

—

251,193

136

—

251,329

Cash and cash equivalents at beginning of period

—

26,413

3,378

—

29,791

Cash and cash equivalents at end of period

—

277,606

3,514

—

281,120

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

This report contains forward-looking statements made pursuant to the safe harbor provisions of the Private Securities Litigation Reform Act of 1995. Forward-looking statements include all statements that do not relate solely to current or historical fact, but address events or developments that we anticipate will occur in the future. Forward-looking statements include statements regarding our goals, beliefs, plans or current expectations, taking into account the information currently available to our management. When we use words such as “anticipate,” “intend,” “expect,” “believe,” “plan,” “may,” “should” or “would” or other words that convey uncertainty of future events or outcome, we are making forward-looking statements. Statements relating to future sales, earnings, operating performance, restructuring strategies, capital expenditures and sources and uses of cash, for example, are forward-looking statements.

These forward-looking statements are subject to various risks and uncertainties which could cause actual results to differ materially from those stated or implied by such forward-looking statements. We undertake no obligation to publicly release any revision of any forward-looking statements contained herein to reflect events and circumstances occurring after the date hereof, or to reflect the occurrence of unanticipated events. Information concerning risk factors is contained under Item “1A - Risk Factors” in our Annual Report on Form 10-K for the year ended December 31, 2006. You should carefully consider all of the risks and all other information contained in or incorporated by reference in this report and in our filings with the SEC. These risks are not the only ones we face. Additional risks and uncertainties not presently known to us, or which we currently consider immaterial, also may adversely affect us. If any of these risks actually occur, our business, financial condition and results of operations could be materially and adversely affected.

Company Overview

Aventine is a leading producer and marketer of ethanol. Through our own production facilities, marketing alliances with other ethanol producers and our purchase/resale operations, we market and distribute ethanol to many of the leading energy companies in the U.S. We have a comprehensive national distribution network utilizing trucks, a leased railcar and barge fleet and a terminal network at critical points on the nation’s transportation grid where our ethanol is blended with our customers’ gasoline. Aventine is also a marketer and distributor of biodiesel. In addition to producing ethanol, our facilities also produce several co-products including: corn gluten feed and meal, corn germ, condensed corn distillers solubles, dried distillers grain with solubles, wet distillers grain with solubles, carbon dioxide and brewers’ yeast.

Results of Operations

The following discussion summarizes the significant factors affecting the consolidated operating results of the Company for the three-month periods ended March 31, 2007 and 2006. This discussion should be read in conjunction with the unaudited condensed consolidated financial statements and notes to the unaudited condensed consolidated financial statements contained in Item 1 above, and the consolidated financial statements and related notes for the year ended December 31, 2006 included in the Company’s Annual Report on Form 10-K.

Our revenues are principally derived from the sale of ethanol and from the sale of co-products (corn gluten feed and meal, corn germ, condensed corn distillers solubles, carbon dioxide, dry distillers grain with solubles (“DDGS”), wet distillers grains with solubles (“WDGS”) and brewers’ yeast) that we

produce as by-products during the production of ethanol at our plants, which we refer to as co-product revenues. We sell ethanol obtained from the following sources:

· Ethanol we manufacture at our plants;

· Ethanol we purchase from our marketing alliance partners; and

· Ethanol we purchase on the spot market.

We market and sell ethanol without regard to whether we produced it, are marketing it for our marketing alliance partners or purchased it on the spot market for resale. In addition to ethanol, we also purchase and market biodiesel.

Executive Summary

We generated net income of $14.9 million, or $0.35 per diluted share in the first quarter of 2007, as compared to net income of $12.2 million, or $0.34 per diluted share, in the first quarter of 2006. Net income increased approximately 22% year over year. We were able to achieve both increased earnings and improved operating performance in a difficult and volatile commodity environment. Revenue in the first quarter of 2007 was $436.7 million, an increase of $123.2 million, or 39.3%, over first quarter 2006 revenue of $313.5 million. The increase is mainly the result of an increase in gallons sold, along with pricing gains caused by the significant year over year rise in the price per gallon of ethanol and from an increase in co-product sales. The average sales price per gallon of ethanol in the first quarter of 2007 was $2.10 per gallon, up from $1.79 per gallon in the same quarter in 2006.

Gallons of ethanol sold in the first quarter of 2007 increased 17.2% to 193.2 million gallons, as compared to 164.9 million gallons in the first quarter of 2006. Ethanol production in the quarter was a record 48.9 million gallons, up from 36.7 million gallons in the first quarter of 2006. In January 2007, our new Pekin dry mill began full production, and we began to realize the benefits from the production capacity increase.

Gross profit totaled $28.4 million in the first quarter of 2007, a decrease of $2.2 million, or 7.2%, from the first quarter of 2006. The decline in gross profit was principally the result of a lower commodity spread caused by higher corn prices. Our corn costs during the first quarter of 2007 averaged $3.58 per bushel, significantly higher than our first quarter 2006 cost of $2.12 per bushel.

We issued $300 million in fixed-rate, unsecured notes, as well as established a new $200 million secured revolving credit facility.

For the Three Months Ended March 31, 2007 Compared to the Three Months Ended March 31, 2006

Total gallons sold in the first quarter of 2007 were 193.2 million gallons, versus 164.9 million gallons sold in the first quarter of 2006, an increase of 28.3 million gallons or 17.2%. Gallons sourced were as follows:

	For the Three Months Ended March 31,				Increase/		% Increase/
(In thousands, except for percentages)	2007		2006		(Decrease)		(Decrease)
Equity production	48,907		36,676		12,231		33.3	%
Marketing alliance purchases	134,709		120,612		14,097		11.7	%
Purchase/resale	21,528		14,424		7,104		49.3	%
Decrease/(increase) in inventory	(11,956	)	(6,859	)	(5,097	)	N.M.*
Total	193,188		164,853		28,335		17.2	%

* N.M. — not meaningful

Net sales in the first quarter of 2007 increased 39.3% from the first quarter of 2006. Net sales were $436.7 million in the first quarter of 2007 versus $313.5 million in the first quarter of 2006. Overall, the increase in net sales was the result of a combination of an increase in the number of gallons sold and an increase in the average sales price of ethanol. The average gross selling price of ethanol in the first quarter of 2007 was $2.10 per gallon, up from the $1.79 received in the first quarter of 2006. Demand for ethanol continued to outpace supply, resulting in continued higher ethanol prices.

Co-product revenue for the first quarter of 2007 totaled $23.1 million, an increase of $8.3 million or 56.1%, from the first quarter of 2006 total of $14.8 million. Co-product revenue increased during the first quarter of 2007 principally from higher average selling prices and also, to a lesser extent, from an increase in co-product tonnage sold as a result of the DDGS produced from the new dry mill production. In the first quarter of 2007, we sold 267.1 thousand tons, versus 248.3 thousand tons in the first quarter of 2006. Co-product returns, as a percentage of the price of corn, were 35.7% during the first quarter of 2007, versus 50.7% in the first quarter of 2006. Co-product returns, as a percentage of the price of corn, decreased in the first quarter of 2007 as compared to 2006 as the result of increases in the price of corn continuing to outpace the increase in co-product pricing, and from the mix of co-products produced. Due to the addition of the new dry mill in Pekin, the increase in DDGS production increased the percentage of the lower value DDGS to the overall mix of available co-products.

Cost of goods sold for the quarter ended March 31, 2007 was $408.2 million, compared to $282.9 million for the quarter ended March 31, 2006, an increase of $125.3 million or 44.3%. Cost of goods sold consists of the cost to produce ethanol at our own facilities, the cost of purchasing ethanol from our marketing alliance partners and from unaffiliated producers and marketers, freight and logistics costs and the cost of motor fuel taxes which have been billed to customers. The increase in cost of goods sold is principally the result of higher costs for purchased ethanol and increased corn costs.

Purchased ethanol in the first quarter of 2007 totaled $300.9 million, versus $223.6 million in the first quarter of 2006. The increase in purchased ethanol results from an increase in both the number of gallons of ethanol purchased, along with increases in the cost per gallon of ethanol. In the first quarter of 2007, we purchased 156.2 million gallons of ethanol at an average cost of $1.93 per gallon as compared to 135.0 million gallons of ethanol at an average cost of $1.66 in the first quarter of 2006.

Production costs include corn costs, conversion costs (defined as the cost of converting the corn into ethanol, and includes production salaries, wages and stock compensation costs, fringe benefits, utilities (including coal and natural gas), maintenance, denaturant, insurance, materials and supplies and other miscellaneous production costs) and depreciation and amortization. Corn costs in the first quarter of 2007 totaled $64.7 million or $3.58 per bushel, versus $29.2 million, or $2.12 per bushel in the first quarter of 2006. The increase in corn costs is principally the result of a perceived increased demand by the marketplace as a result of expected new ethanol production facilities being built. Conversion costs for the first quarter of 2007 increased to $27.0 million from $20.3 million for the first quarter of 2006. The total dollars spent on conversion costs increased year over year as a result of the new Pekin dry mill production. However, the conversion cost per gallon remained constant year over year at $0.55 per gallon.

Depreciation in the first quarter of 2007 totaled $2.9 million, versus $1.0 million in the first quarter of 2006. The increase in depreciation expense is the result of the new Pekin dry mill beginning production. Motor fuel taxes were $6.2 million in the first quarter of 2007 versus $1.6 million in the first quarter of 2006. The cost of motor fuel taxes are recovered through billings to customers.

Freight/logistics costs in the first quarter of 2007 increased to $30.2 million, or approximately $0.16 per gallon, from $20.8 million, or $0.13 per gallon in the first quarter of 2006. The increase in freight/logistics cost is the result of higher transportation expenses, fuel surcharges and from the expansion of our distribution system footprint.

Selling, general and administrative expenses (“SG&A”) expenses were $9.6 million in the first quarter of 2007, compared to $6.3 million in the first quarter of 2006. SG&A expenses increased as a result of increased costs related to being a public company, and from costs associated with the expansion and growth of our business. Year over year increases in SG&A costs are primarily due to increased costs related to legal and other professional fees associated with our being a public company, including increased legal fees related to our capacity expansion efforts, the costs of complying with Section 404 of Sarbanes-Oxley Act of 2002, higher insurance costs related to directors and officers insurance, and increased personnel costs, including increased non-cash stock-based compensation expense and fringe benefits.

Interest income in the first quarter of 2007 was $1.4 million, versus $0.7 million in the first quarter of 2006. The increase in interest income is due to a combination of a higher average level of funds available to invest as a result of cash received from our initial public offering and our recent Note offering, along with better operating results. This was offset by increased short-term investment rates due to increases in interest rates in general.

Interest expense in the first quarter of 2007 was $0.3 million, as compared to $4.4 million in the first quarter of 2006. Interest expense was lower in the first quarter of 2007 due to the July 2006 repurchase of $160 million aggregate principal amount of our notes, versus the first quarter of 2006 when all $160 million of the notes were still outstanding. The interest expense in the first quarter of 2007 relates to the $300 million of 10% fixed-rate unsecured notes issued in late March 2007.

The minority interest for the quarter ended March 31, 2007 was a $0.5 million charge to income compared to $1.3 million charge to income for the quarter ended March 31, 2006. This decrease reflects the reduced operating performance of our Nebraska subsidiary caused primarily by the year over year significant increase in corn costs.

Other non-operating income for the first quarter of 2007 includes $3.9 million of realized and unrealized gains on corn derivative contracts, including the effect of marking to market derivative contracts, versus gains in the first quarter of 2006 of $0.6 million. Other non-operating income is impacted by the CBOT prices for derivative contracts.

The income tax rate for the first quarter of 2007 was 36.1% versus a rate of 39.6% in the first quarter of 2006. The lower rate in the first quarter of 2007 resulted from lower state rates now being accrued as compared to the first quarter of 2006. The income tax rate for the first quarter of 2007 also includes a component for interest expense related to uncertain tax positions in accordance with FASB Interpretation No. 48, Accounting for Uncertainty in Income Taxes- an interpretation of FASB Statement No. 109.

Trends and Factors that May Affect Future Operating Results

Ethanol Pricing

As of March 31, 2007, we had contracts for delivery of ethanol totaling 199.1 million gallons for delivery throughout the remainder of 2007, which represents approximately 36% of our expected ethanol shipments for the remainder of the year. These commitments were for 40.6 million gallons at an average

fixed price of $1.96, 31.6 million gallons at an average positive spread to wholesale gasoline of $0.43 (based upon the NYMEX, Chicago and NY harbor indices), and 126.9 million gallons at spot prices (using various Platt, OPIS and AXXIS indices). Although these contracts are for delivery throughout 2007, they are heavily weighted towards the second and third quarters of 2007.

Corn Pricing

Based on our current hedges and current market conditions, we estimate our corn costs for the second quarter of 2007 will be in the $3.95 to $4.00 per bushel range, and our third quarter 2007 corn costs will be in the $3.90 to $3.95 per bushel range, excluding any effects of mark to market adjustments on our hedge positions.

Marketing Alliance

During the first quarter of 2007, we signed seven new alliance partner agreements with planned projects totaling 656 million gallons of production capacity when completed. The new alliance partner agreements include the two new plants associated with an affiliate of Sir Richard Branson’s Virgin Group and Bioverda International Holdings Limited (Indiana Bio-Energy and Ethanol Grain Processors), two new proposed Panda Energy plants (Yuma, Colorado and Haskell County, Kansas), two new proposed E Energy plants (Auburn, Nebraska and Broken Bow, Nebraska), and a new proposed ethanol plant in Dadeville, Alabama.

As of April 1, 2007, VeraSun Energy Corporation is no longer part of our marketing alliance. In the second quarter of 2007, we expect two new marketing alliance partner plants to begin producing ethanol, adding approximately 74 million gallons of ethanol annually to our existing marketing alliance volume. As of April 1, 2007, our marketing alliance partners have nameplate capacity to produce 287 million gallons of ethanol annually. We have also signed contracts to market an additional 1.4 billion gallons of ethanol from existing and new marketing alliance partners who have projects currently under construction, and for projects which have been proposed. 325 million gallons of this amount is currently under construction. We believe these plants currently under construction will be completed and we expect to market these additional gallons. These plants are expected to come online between April 2007 and December 2008. In addition, we have also signed marketing agreements for another 1.1 billion gallons of annual capacity for proposed projects. Construction of these proposed projects has not commenced, and there can be no assurances that these projects will be commenced or completed on a timely basis, or at all.

Supply and Demand

It is expectsed that annual ethanol production capacity in the U.S. will total in excess of 7.5 billion gallons annually by the end of 2007, which is the amount required by the existing renewable fuel standard for 2012. Ethanol produced in the United States competes with sugar-based ethanol produced in Brazil. This additional capacity, along with imports, may cause supply to exceed demand. If additional demand for ethanol is not created, either through additions to discretionary blending (through increased penetration rates in areas that blend ethanol today or through the establishment of new markets where little or no ethanol is blended today), or through additional governmental mandates at either the federal or state level, the excess supply may cause ethanol prices to decrease, perhaps substantially.

Expansion

We have announced plans to expand capacity by up to an aggregate of 565 million gallons. We are currently negotiating engineering, procurement and construction (“EPC”) contracts for 113 million

gallon facilities at each of Mount Vernon, Indiana and Aurora, Nebraska. We expect the cost to build the first 113 million gallon phases of these projects to be $2.00 to $2.10 per gallon. We also plan to spend another $15 million at each site as part of the first 113 million gallon phases in preparation for the second 113 million expansion phases. We have not yet received permits to begin construction at any of the proposed sites, although permit applications have been filed. The timing of such expansions and the final terms of the EPC contracts may have a material affect on our results of operations. In addition, we may have to pay penalties or damages under certain contracts related to such capacity expansions. For a discussion of these potential penalties and damages see “Liquidity and Capital Resources — Overview and Outlook” below.

Bio-Diesel

In March 2007, we announced that we had entered the biodiesel marketing business. We have launched a marketing program for biodiesel similar to our ethanol marketing program. We shipped biodiesel to customers in the first quarter of 2007.

Liquidity and Capital Resources

Overview and Outlook

The following table sets forth selected information concerning our financial condition:

(In thousands)	March 31, 2007 (Unaudited)		December 31, 2006
Cash and cash equivalents	$	281,120	$	29,791
Short-term investments	144,750		98,925
Working capital	502,838		203,247
Total debt	300,000		—
Current ratio	7.02		3.44

In March 2007, we completed a private placement of $300 million of senior unsecured notes due 2017. These 10-year notes have a fixed interest rate of 10%.

On March 23, 2007, the Company, through certain of its indirect subsidiaries (Aventine Renewable Energy, Inc., Aventine Renewable Energy — Mt Vernon, LLC and Aventine Renewable Energy — Aurora West, LLC), established a new five-year $200 million senior secured revolving credit facility that may, under certain circumstances, increase in amount up to $300 million. The facility will be funded by a consortium of banks, led by JPMorgan Chase Bank, N.A.

With our current cash balances, amounts available under our secured revolving credit facility and anticipated cash flow from operations, we believe that we will be able to satisfy existing anticipated working capital needs, debt service obligations, capital expenditure and other anticipated cash requirements for the remainder of the year.

The amount of capital expenditures necessary to build our proposed 113 million gallon dry mill expansion in Pekin, Illinois, our proposed 226 million gallon plant adjacent to our Nebraska facility and our proposed 226 million gallon plant in Mount Vernon, Indiana, is currently estimated to be between $1.90 and $2.00 per denatured gallon of capacity, or a total of approximately $1.1 billion. We are contractually obligated, subject to certain conditions, including obtaining necessary permits, to develop both a 113 million gallon plant adjacent to our Nebraska facility (using commercially reasonable best efforts to obtain a permit for 226 million gallon capacity) and a 226 million gallon plant in Mount

Vernon, Indiana. If we do not meet certain specified milestones, we will be subject to penalties. The contract to complete the 226 million gallon expansion adjacent to our Nebraska facility provides for liquidated damages not exceeding $5 million if specified milestones are not met or we do not construct a facility with a capacity of at least 110 million gallons. If such penalties are not paid, the counterparty to the contract has the right to repurchase the property at cost (subject to adjustment for any expenses, which we have paid with respect to infrastructure construction). In certain cases, the counterparty can agree to an extension and limited cure rights for payments. The contract for completion of the 226 million gallon plant in Mount Vernon, Indiana provides that, if we do not meet certain milestones, subject to specified extension rights and cure periods, we will be in default under our lease with the Indiana Port Commission. The State of Indiana may complete construction of the plant at our expense if we fail to do so. The contract does not provide for liquidated damages as an alternative. In addition, we would also be subject to certain other penalties provided for in the lease. Notwithstanding the above, if, despite our diligent efforts, we are unable to obtain permits for the Mt. Vernon facility by a certain date, we can negotiate a waiver of the compliance date and establish a new date for compliance. If we do not reach an agreement, either the Mount Vernon lessor or we can terminate the Mount Vernon lease. Accordingly, we cannot estimate the amount of damages we could be liable for.

In March 2007, we signed a $102 million contract with Delta-T Corporation for the purchase of long lead-time equipment for the proposed Mount Vernon and Aurora West facilities. We also signed a $12 million contract with Kiewit Energy Company for initial site work at Aurora West. We expect to have the engineering, procurement and construction contracts for these facilities executed shortly, and expect to begin construction of 113 million gallon plants at each of Mount Vernon, Indiana and in Aurora, Nebraska this summer.

Sources of Liquidity

Our principal sources of liquidity are cash, short-term investments, cash provided by operations, and cash available under our secured revolving credit facility.

Cash and short-term investments. For the first three months of 2007, cash and short-term investments increased by $297.2 million. Cash and short-term investments as of March 31, 2007 and December 31, 2006 were $425.9 million and $128.7 million, respectively. The increase in cash and short-term investments is principally the result of cash received from the private placement of $300 million aggregate principal amount of senior unsecured 10% fixed rate notes, net of fees, and from cash provided by operations.

Cash provided by operations. Net cash provided by operating activities in the first three months of 2007 was $18.0 million, as compared to cash provided by operating activities of $8.1 million for the first three months of 2006. The increase in cash provided by operations in 2007 versus 2006 is primarily the result of improved earnings and a reduction in accounts receivable, offset by growth in inventory. In the first quarter of 2006, cash provided by operations was negatively affected by increases in inventory that grew faster than reductions in receivables. Cash on our balance sheet, along with the cash received from the issuance of the $300 million of 10% senior unsecured notes, along with continued strong pricing and demand for ethanol, has significantly helped our working capital position.

Cash available under our liquidity facility. During the first quarter of 2007, we put into place a new five-year $200 million senior secured revolving liquidity facility that may, under certain circumstances, increase in amount up to $300 million. We had no borrowings outstanding under our secured revolving credit facility at March 31, 2007 and $1.2 million of standby letters of credit outstanding, leaving approximately $88.7 million in additional borrowing availability thereunder as of that date. As of December 31, 2006, we had no borrowings outstanding under our previous secured

revolving credit facility and $4.0 million of standby letters of credit outstanding, leaving approximately $26.0 million in additional borrowing availability under the previous secured revolving credit facility as of that date. A fixed asset component in an amount of $50 million may be added to the borrowing base under our new senior secured revolving liquidity facility on or prior to December 31, 2007 upon the satisfaction of certain requirements. We are in the process of satisfying the requirements necessary in order to take advantage of this fixed asset component.

Uses of Liquidity

Our principal uses of liquidity are capital expenditures, payments related to our outstanding debt and liquidity facility, and the repurchase of shares of our common stock.

Capital expenditures. In the first three months of 2007, capital expenditures (excluding expansion related expenditures) totaled $2.7 million versus $1.0 million in the first three months of 2006. Capital expenditures include asset replacement, environmental and safety compliance and cost reduction and productivity improvement items. Our capital spending plan for all of 2007, excluding our expansion projects, is forecasted to be between $20 and $22 million.

Capital expenditures related to our announced expansion projects totaled $9.7 million in the first three months of 2007. In addition, we announced on March 20, 2007 that we had entered into two contracts related to expansion of our capacity at Mount Vernon, Indiana and Aurora, Nebraska. We entered into an Advance Work Agreement in the amount of $102 million, effective as of March 12, 2007, with Delta-T Corporation, for the purchase of plant equipment in advance of the completion of negotiations of an engineering, procurement and construction (“EPC”) agreement with Kiewit Energy Company (“Kiewit”). The $102 million in payments will be made between March 2007 and May 2008. In addition, we also announced on March 20, 2007 an agreement with Kiewit for Pre-EPC consulting and contracting services in the amount of $12.0 million in order to expedite the performance of certain tasks related to the design and construction of our proposed Aurora, Nebraska ethanol facility. Payments under the Kiewit contract will begin in March 2007 and continue until August 2007.

We expect to spend approximately $250 million in total during 2007 on capacity related expenditures.

Payments related to our outstanding debt and liquidity facility. In the first three months of 2007, we did not make any interest payments on our debt and our liquidity facility. In the first three months of 2006, we paid $4.2 million in interest payments on our debt and liquidity facility.

Repurchase of shares of common stock. In the first quarter of 2007, we did not repurchase any shares of our common stock under the share repurchase program approved by our Board of Directors. The share repurchase program allows the repurchase of up to $50 million of our outstanding common stock, although there are no minimum share purchase requirements. There is approximately $48.8 million available to be repurchased under this program.

Environmental Matters

We are subject to extensive federal, state and local environmental laws, regulations and permit conditions (and interpretations thereof), including those relating to the discharge of materials into the air, water and ground, the generation, storage, handling, use, transportation and disposal of hazardous materials, and the health and safety of our employees. These laws, regulations, and permits require us to incur significant capital and other costs, including costs to obtain and maintain expensive pollution control equipment. They may also require us to make operational changes to limit actual or potential

impacts to the environment. A violation of these laws, regulations or permit conditions can result in substantial fines, natural resource damages, criminal sanctions, permit revocations and/or facility shutdowns. In addition, environmental laws and regulations (and interpretations thereof) change over time, and any such changes, more vigorous enforcement policies or the discovery of currently unknown conditions may require substantial additional environmental expenditures.

We are also subject to potential liability for the investigation and cleanup of environmental contamination at each of the properties that we own or operate and at off-site locations where we arranged for the disposal of hazardous wastes. From time to time, hazardous material spills have occurred at our facilities or properties, which we investigate and remediate as necessary. Also, soil and groundwater contamination has been identified in the past at our Pekin, Illinois campus. If significant contamination is identified at our properties in the future, costs to investigate and remediate this contamination as well as any costs to investigate or remediate associated natural resource damages could be significant. If any of these sites are subject to investigation and/or remediation requirements, we may be responsible under CERCLA or other environmental laws for all or part of the costs of such investigation and/or remediation, and for damages to natural resources. We may also be subject to related claims by private parties alleging property damage or personal injury due to exposure to hazardous or other materials at or from such properties. We have not accrued any amounts for environmental matters as of March 31, 2007. The ultimate costs of any liabilities that may be identified or the discovery of additional contaminants could adversely impact our results of operation or financial condition.

In addition, the hazards and risks associated with producing and transporting our products (such as fires, natural disasters, explosions, abnormal pressures and spills) may result in spills or releases of hazardous substances, and may result in claims from governmental authorities or third parties relating to actual or alleged personal injury, property damage, or damages to natural resources. We maintain insurance coverage against some, but not all, potential losses caused by our operations. Our coverage includes, but is not limited to, physical damage to assets, employer’s liability, comprehensive general liability, automobile liability and workers’ compensation. We do not carry environmental insurance. We believe that our insurance is adequate for our industry, but losses could occur for uninsurable or uninsured risks or in amounts in excess of existing insurance coverage. The occurrence of events which result in significant personal injury or damage to our property, natural resources or third parties that is not covered by insurance could have a material adverse impact on our results of operations and financial condition.

Our air emissions are subject to the federal Clean Air Act, the federal Clean Air Act Amendments of 1990 and similar state laws which generally require us to obtain and maintain air emission permits for our ongoing operations as well as for any expansion of existing facilities or any new facilities. Obtaining and maintaining those permits requires us to incur costs, and any future more stringent standards may result in increased costs and may limit or interfere with our operating flexibility. In addition, the permits ultimately issued may impose conditions which are more costly to implement than we had anticipated. These costs could have a material adverse affect on our financial condition and results of operations. Because other ethanol manufacturers in the U.S. are and will continue to be subject to similar laws and restrictions, we do not currently believe that our costs to comply with current or future environmental laws and regulations will adversely affect our competitive position. However, because ethanol is produced and traded internationally, these costs could adversely affect us in our efforts to compete with foreign producers not subject to such stringent requirements.

Federal and state environmental authorities have been investigating alleged excess VOC emissions and other air emissions from many U.S. ethanol plants, including our Illinois and Nebraska facilities. The matter relating to our Illinois wet mill facility is still pending, and we could be required to

install additional air pollution control equipment or take other measures to control air pollutant emissions at that facility. If authorities require us to install controls, we would anticipate that costs would be higher than the costs we incurred for this matter at our Nebraska facility due to the larger size of the Illinois wet mill facility. In addition, if the authorities determine our emissions were in violation of applicable law, we would likely be required to pay fines that could be material.

We have made, and expect to continue making, significant capital expenditures on an ongoing basis to comply with increasingly stringent environmental laws, regulations and permits. We have included in our capital budget for 2007 approximately $10.8 million for projects relating to environmental, health and safety matters, including for the installation of air pollution control equipment and for wastewater discharge improvements at our Illinois wet mill facility. As of March 31, 2007, we have spent approximately $0.2 of this amount. The majority of the 2007 environmental capital budget relates to compliance with the EPA’s final National Emissions Standard for Hazardous Air Pollutants, or NESHAP, under the federal Clean Air Act for industrial, commercial and institutional boilers and process heaters. This NESHAP will require us to implement maximum achievable control technology at our Illinois wet mill facility to reduce hazardous air pollutant emissions from certain of our boilers and process heaters by September 13, 2007. Based on engineering conducted to date and currently available information, we have budgeted $7.4 million to comply with this NESHAP in 2007. Due to various reasons, including equipment delivery delays, however, we may not be able to meet the September 2007 deadline. We are continuing to discuss a deadline extension with the state authorities. If an extension is not granted, and we do not meet the September 2007 deadline, fines and penalties could be imposed on us, which could be substantial.

We currently generate revenue from the sale of carbon dioxide, which is a co-product of the ethanol production process at each of our Illinois and Nebraska facilities. New laws or regulations relating to the production, disposal or emissions of carbon dioxide may require us to incur significant additional costs and may also adversely affect our ability to continue generating revenue from carbon dioxide sales.

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. We do not enter into derivatives or other financial instruments for trading or speculative purposes.

Commodity Price Risks

We are subject to market risk with respect to the price and availability of corn, the principal raw material we use to produce ethanol and ethanol by products. In general, rising corn prices result in lower profit margins and, therefore, represent unfavorable market conditions. This is especially true when market conditions do not allow us to pass along increased corn costs to our customers. The availability and price of corn is subject to wide fluctuations due to unpredictable factors such as weather conditions, farmer planting decisions, governmental policies with respect to agriculture and international trade and global demand and supply. Our weighted average gross corn costs for the three months ended March 31, 2007 and 2006 was $3.58 and $2.12 per bushel, respectively.

We have firm-price purchase commitments with some of our corn suppliers under which we agree to buy corn at a price set in advance of the actual delivery of that corn to us. At March 31, 2007,

we had commitments to purchase approximately 21.3 million bushels of corn through December 2009 at an average price of $4.05 per bushel from these corn suppliers. Under these arrangements, we assume the risk of a price decrease in the market price of corn between the time this price is fixed and the time the corn is delivered. In order to reduce our market exposure to price decreases, at the time we enter into a firm-price purchase commitment, we also often enter into commodity forward contracts to sell a like amount of corn at the then-current price for delivery to the counterparty at a later date. We account for these transactions under Statement of Financial Accounting Standard No. 133, Accounting for Derivative Instruments and Hedging Activities, as amended by Statement of Financial Accounting Standard No. 138, Accounting for Certain Derivative Instruments and Certain Hedging Activities, and by Statement of Financial Accounting Standard No. 149, Amendment of Statement 133 on Derivative Instruments and Hedging Activities, (hereinafter collectively referred to as “SFAS 133”). These forward contracts are not designated as hedges and, therefore, are marked to market each period, with corresponding gains and losses recorded in other non-operating income. The fair value of these derivative assets is recognized in other current assets in the Condensed Consolidated Balance Sheet, net of any cash received from the brokers. Information on this type of derivative transaction is as follows:

(In millions)	March 31,2007
Realized and unrealized gains included in earnings	$	1.1

(In millions)	March 31, 2007
Net bushels sold	10.5
Aggregate notional value of derivatives outstanding	$	40.8
Period through which derivative positions currently exist	December 2009
Unrealized gain on the fair value of outstanding derivative positions	$	0.7
The change in fair value due to the effect of a 10% adverse change in commodity prices to current fair value	$	(4.3	)

We have also sold put contracts on corn to protect ourselves should corn prices fall. We account for these transactions under SFAS 133. These put contracts are not designated as hedges and, therefore, are marked to market each period, with corresponding gains and losses recorded in other non-operating income. The fair value of these derivative assets is recognized in other current assets in the Condensed Consolidated Balance Sheet, net of any cash received from the brokers. Information on this type of derivative transaction at March 31, 2007 is as follows:

(In millions)	March 31, 2007
Realized and unrealized gains included in earnings	$	2.8

(In millions, except premium paid and strike price)	March 31, 2007
Net bushels covered by puts	8.6
Average premium paid for puts (in cents per bushel)	11.4
Strike price of put positions	$	3.80
Period through which derivative positions currently exist	July 2007
Unrealized gains on the fair value of outstanding put positions	$	1.3
The change in fair value due to the effect of a 10% adverse change in commodity prices to current fair value	$	(0.4	)

Material Limitations

The disclosures with respect to the above noted risks do not take into account the underlying commitments or anticipated transactions. If the underlying items were included in the analysis, the gains

or losses on the futures contracts may be offset. Actual results will be determined by a number of factors that are not generally under our control and could vary significantly from those factors disclosed.

We are exposed to credit losses in the event of nonperformance by counterparties on the above instruments, as well as credit or performance risk with respect to our hedged commitments. Although nonperformance is possible, we do not anticipate nonperformance by any of these parties.

Item 4. Controls and Procedures

Evaluation of Disclosure Controls and Procedures

Under the supervision of, and with the participation of management, including our Chief Executive Officer, Ronald H. Miller, and our Chief Financial Officer, Ajay Sabherwal, the Company carried out an evaluation of the effectiveness of our disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e) under the Securities Exchange Act of 1934, as amended (the “Exchange Act”)) as of the end of the period covered by this report. Based upon that evaluation, Messrs. Miller and Sabherwal have concluded that, as of the end of the period covered by this report, the Company’s disclosure controls and procedures have been designed and are effective to provide reasonable assurance that information required to be disclosed in the reports filed or submitted under the Exchange Act is recorded, processed, summarized and reported within the time periods specified in the rules and forms of the Securities and Exchange Commission. These disclosure controls and procedures include, without limitation, controls and procedures designed to provide reasonable assurance that information required to be disclosed in such reports is accumulated and communicated to our management, including Messrs. Miller and Sabherwal, as appropriate to allow timely decisions regarding the required disclosure. The design of any system of controls is based in part upon certain assumptions about the likelihood of future events. There can be no assurance that any design will succeed in achieving its stated goal under all potential future conditions, regardless of how remote.

Changes in Internal Control over Financial Reporting

Based upon evaluation by our management, which was conducted with the participation of Messrs. Miller and Sabherwal, there has been no change in our internal control over financial reporting during the period covered by this report that has materially affected, or is reasonably likely to materially affect, our internal control over financial reporting.

PART II. OTHER INFORMATION

Item 1. Legal Proceedings

None

Item 1A. Risk Factors

The Company has included in its Annual Report on Form 10-K as of December 31, 2006 a description of certain risks and uncertainties that could affect the Company’s business, future performance or financial condition (“Risk Factors”). Those Risk Factors are hereby incorporated in Part II, Item 1A of this Form 10-Q.

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

None

Item 3. Defaults Upon Senior Securities

None

Item 4. Submission of Matters to a Vote of Security Holders

None

Item 5. Other Information

None

Item 6. Exhibits

(a) Exhibits

4.1 Indenture, dated as of March 27, 2007, among the Company, the subsidiary guarantors named therein, and Wells Fargo Bank, N.A. and the form of note (incorporated by reference to Exhibit 4.1 to the Company’s Current Report on Form 8-K filed on April 2, 2007).

10.1 Advance Work Agreement, dated as of March 12, 2007, between the Company and Delta-T Corporation, for the purchase of plant equipment in advance of the completion of negotiations of an engineering, procurement and construction agreement with Kiewit Energy Company.

10.2 Pre-engineering, procurement and construction consulting and contracting services contract, dated as of March 17, 2007, between the Company and Kiewit Energy Company, for the performance of certain tasks related to the design and construction of the Company’s proposed Aurora, Nebraska ethanol facility.

10.3 Form of Performance Stock Unit Award Agreement (2003 Stock Incentive Plan) (incorporated by reference to Exhibit 10.1 to the Company’s Current Report on Form 8-K filed on February 27, 2007).

10.4 Form of Stock Option Agreement (2003 Stock Incentive Plan) (incorporated by reference to Exhibit 10.2 to the Company’s Current Report on Form 8-K filed on February 27, 2007).

10.5 Form of Restricted Stock Agreement (2003 Stock Incentive Plan) (incorporated by reference to Exhibit 10.3 to the Company’s Current Report on Form 8-K filed on February 27, 2007).

10.6 Form of Non-employee Director Restricted Stock Agreement (2003 Stock Incentive Plan (incorporated by reference to Exhibit 10.4 to the Company’s Current Report on Form 8-K filed on February 27, 2007).

10.7 Purchase Agreement, dated as of March 21, 2007, among the Company, the subsidiary guarantors named therein and J.P. Morgan Securities, Inc., as representative of several initial purchasers (incorporated by reference to Exhibit 10.1 to the Company’s Current Report on Form 8-K filed on March 27, 2007).

10.8 Credit Agreement, dated as of March 23, 2007, by and among Aventine Renewable Energy, Inc., Aventine Renewable Energy — Mt Vernon, LLC and Aventine Renewable Energy — Aurora West, LLC, the other Loan Parties thereto, the lenders thereto and JPMorgan Chase Bank, N.A., as administrative agent (incorporated by reference to Exhibit 10.1 to the Company’s Current Report on Form 8-K filed on March 26, 2007).

10.9 Registration Rights Agreement, dated as of March 27, 2007, among the Company, the subsidiary guarantors named therein and Wells Fargo Bank, N.A. (incorporated by reference to Exhibit 10.1 to the Company’s Current Report on Form 8-K filed on April 2, 2007).

10.10 Form of Aventine Renewable Energy Holdings, Inc. 2003 Stock Incentive Plan (Amended and Restated as of April 16, 2007) (incorporated by reference to Exhibit 10.1 to the Company’s Current Report on Form 8-K filed on April 16, 2007).

31.1 Certification of the Chief Executive Officer pursuant to Section 302 of the Sarbanes- Oxley Act of 2002.

31.2 Certification of the Chief Financial Officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.

32.1 Certification of the 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 the Chief Financial Officer pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.

SIGNATURE

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 thereto duly authorized.

	AVENTINE RENEWABLE ENERGY HOLDINGS, INC.


Dated: May 9, 2007	By:	/s/	William J. Brennan
	Name:		William J. Brennan
	Title:		Principal Accounting Officer

Exhibit 10.1

ADVANCE WORK AGREEMENT

THIS ADVANCE WORK AGREEMENT (this “Agreement”) is made as of this 12th day of March, 2007, by and between Aventine Renewable Energy Holdings, Inc. (“Client”) and Delta-T Corporation (“Delta-T”) (Client and Delta-T are referred to herein as the “Parties”)

RECITALS:

WHEREAS, Client wishes to expedite the purchasing of plant equipment in advance of completing the negotiation of an engineering, procurement and construction (“EPC”) contract(s) with Kiewit Energy Company (“Kiewit”);

WHEREAS, Client desires to enter into an EPC Contract(s) with Kiewit whereby it is contemplated that Delta-T will provide, certain engineering, procurement and technology services for up to three (3) ethanol plants, one (1) with a design capacity of 108 million gallons per year and two (2) with a design capacity of 108 million gallons per year with the capability of being expanded to a design capacity of 216 million gallons per year, of undenatured anhydrous ethanol (the “Plants”).

WHEREAS, Client and Kiewit are presently negotiating terms of the EPC Contract(s), and the Parties wish to arrange for the immediate purchase of certain equipment, as identified herein at Exhibit “A”, by Delta-T on Client’s behalf, prior to the conclusion of the negotiations of the EPC Contract(s).

WHEREAS, Client authorizes Delta-T to begin, and Delta-T agrees to perform, the work described in the attached Exhibit “A” (the “Work”). Delta-T shall perform the Work and Client shall remit payment to Delta-T for the Work in the manner described in this Agreement.

WHEREAS, the purpose of this Agreement is to (i) cause Delta-T to perform the Work in accordance with Exhibit “A” and this Agreement, and (ii) set forth the conditions pursuant to which Delta-T shall perform the Work and receive payments for such performance.

NOW THEREFORE, in consideration of the premises set forth above and the promises contained in this Agreement, the Parties acknowledge good and valuable consideration, and agree as follows:

Article 1 — Undertakings; Relationship Among The Parties The Parties hereby agree to work together under this Agreement for the purposes of ordering long-lead equipment that will be necessary for construction of the Plants, for which it is contemplated Delta-T Technology would be used, prior to Client’s finalizing negotiations and entering into the EPC Contract(s). The equipment for the Plants to be purchased under this Advanced Work Agreement, the progress payments, and the payment dates for such equipment, which have been agreed by the Parties as of the date hereof, are identified in Exhibit “A”. From time to time, as the Parties agree upon additional equipment to be ordered by Delta-T pursuant to the terms of this Agreement, additional Exhibit “A’s” may be added hereto for such equipment, and said items shall also be deemed to constitute “Work” as such term is defined in this Agreement.

Article 2 — Each Party’s Responsibilities Each Party shall be responsible for the following areas in furtherance of the Work:

Client shall forward the amounts specified in Exhibit “A” on the dates and in the amounts as specified in said Exhibit “A” covering the items of equipment referenced in such Exhibit “A” via electronic wire transfer to Delta-T in Williamsburg, Virginia SOLELY for Work to be performed under this Agreement. Upon receipt of the first payment set forth on Exhibit “A”, Delta-T shall promptly begin the Work and proceed to acquire the equipment which is the subject of such authorization in accordance with the Exhibit “A’s” attached to (or hereafter added to) this Agreement. Delta-T shall promptly pay all amounts received from Client by Delta-T to the appropriate vendors or manufacturers of said equipment (less the portions of such amounts representing the portion of Delta-T’s procurement fee included in such amounts). Delta-T shall also promptly provide Client with written documentation from the vendors and manufacturers of the equipment showing payment of said invoices by Delta-T (redacting any cost data). The parties acknowledge that the purpose of this Agreement is to perform the Work only, and not to address all of the potential services to be addressed in the EPC Contract(s) for the Plants. Accordingly, by agreeing to perform the Work described herein, Delta-T does not guarantee the completion of all of the prospective services to be addressed in such EPC Contract(s).

It is agreed and acknowledged that Delta-T shall not be required to perform any Work outside the scope of this Agreement unless the Parties enter into a subsequent written agreement covering such additional work.

Notwithstanding anything to the contrary contained herein, it is agreed and understood that all payments made by Client to Delta-T under this Agreement shall be credited dollar for dollar towards the Contract Price under the EPC Contract(s) for the applicable Plants for which the equipment which is the subject of the Work pertains.

Article 3 — Assignment

3.1 Delta-T hereby agrees that, upon its receipt of payment for the cost of any equipment (as more specifically described in Exhibit “A”) and delivery of such equipment to the Plant site designated by Client, or such other location designated by Client, it shall assign all of its rights, title and interest in and to the equipment to Client. Further, Delta-T shall include language acceptable to Client in its agreements and purchase orders with any vendors or manufacturers of equipment requiring each such manufacturer or vendor to execute reasonable and appropriate documentation evidencing the assignment of ownership, the assignment of all warranties delivered in connection with said equipment, and the assignment of all other rights, title and interest in and to the equipment to Client upon written demand. Delta-T shall identify and assign to Client all warranties received in connection with the Work. If any such warranties are not assignable, then to the extent Delta-T receives any warranties from the equipment vendor or manufacturer, Delta-T shall warrant the same to Client. In addition, upon Delta-T’s receipt of each payment applicable to any equipment set forth on Exhibit “A”, Delta-T hereby grants to Client a first priority security interest in all of Delta-T’s rights or interests in such equipment up to the amount of such payment and agrees to execute such documents as Client may request in order to more fully perfect such security interest. In the event Delta-T fails to complete purchase of said equipment, Client shall have the right to assume any and all contracts and/or purchase

orders for purchase of said equipment, as well as to pursue any other remedies against Delta-T for breach of contract. Except as provided herein, neither Client nor Delta-T may assign or delegate this Agreement or any of its rights or obligations under this Agreement to any third party without the written consent of the other party.

Article 4 — Confidentiality

4.1 Each Party agrees that all data, processes, equipment, technology, know-how, design, specifications, financial information, or other information disclosed to it by the other Party under this Agreement shall be maintained as confidential.

4.2 All obligations to adhere to the previously executed Confidentiality Agreement(s) between the Parties shall remain in full force and effect during the term of this Agreement (as to the information which is the subject of Article 4.1 above), or beyond if provided in such Confidentiality Agreement(s).

Article 5 — Rights In Data

5.1 Nothing in this Agreement shall be interpreted as granting a license to use or transferring any intellectual property rights of any Party, including but not limited to, copyrights, trademarks, trade secrets and patents, unless specifically stated in a separate writing signed by the Parties.

Article 6 — Term of Agreement

6.1 This Agreement shall terminate upon the earliest occurrence of any of the events listed below:

(a) the Parties mutually agree in writing to terminate this Agreement; or

(b) if either Party breaches this Agreement for any reason other than non-payment which is covered under Article 6.1(c), the non-breaching party may terminate this Agreement in the event that the breaching party has not cured such breach within ten (10) business days of receipt of written notice of such breach from the non-breaching party; or

(c) if Client fails to make full payment to Delta-T of any amount owed by the due date specified in Exhibit A, Delta-T may terminate this Agreement if Client has not made such payment within five (5) days of Client’s receipt of written notice from Delta-T of such failure to make such payment; or

(d) completion of the Work under this Agreement; or

(e) upon prior written notice by Client to Delta-T; or

(f) if an EPC Contract or EPC Contracts are not executed within one hundred eighty (180) days from the date of this Agreement for one or more Plants applicable to all of the Work which is the subject of this Agreement, and Client elects to terminate this Agreement by written notice to Delta-T.

In the event of termination in accordance with any subsection (a), (b) or (f) of this Article 6, any payments made to Delta-T by Client and not expended in furtherance of the Work (after subtracting Delta-T’s profit, overhead and contingencies) shall be refunded to Client within ten (10) business days of said termination. In addition, in the event of termination in accordance with Article 6.1(a), 6.1(b) or 6.1(f), Client shall have the option to assume all of Delta-T’s rights and obligations for the purchase of any or all of the equipment included in the Work, and in the event Client exercises such option, Delta-T shall cooperate with Client in having Delta-T’s rights and obligations with respect to the equipment for which Client has exercised such option, transferred to Client.

In the event that an EPC Contract is executed and delivered, all Work performed hereunder applicable to the Plant which is the subject of such EPC Contract (with Client to designate to Delta-T the applicable EPC Contract to which the Work, or portion of the Work, as applicable, pertains) and all payments made hereunder with respect to such Work shall be treated as Work performed and payments made under such EPC Contract. In addition, the Parties acknowledge that all of the terms and conditions set forth in this Agreement applicable to the Work performed, or to be performed, hereunder applicable to the Plant which is the subject of such EPC Contract shall be superseded and replaced in their entirety by the terms and conditions of such EPC Contract following the issuance by Client of the Notice to Proceed under such EPC Contract, including without limitation, the provisions of Articles 10. and 11. As set forth in Article 2, however, all payments under this Agreement applicable to Work for one of the Plants shall be credited dollar for dollar towards the Contract Price under the EPC Contract applicable to such Plant.

Article 7 — Integration

7.1 Except as otherwise provided, this Agreement, together with all Exhibits attached hereto, represents the entire and integrated agreement between the Parties with respect to the subject matter referenced herein. It supersedes all prior agreements with respect to the Work except the Non-Disclosure Agreements referenced above.

Article 8 — Governing Law

8.1 This Agreement shall be governed by and construed in accordance with the laws of the State of Virginia.

Article 9 — Consequential Damages

9.1 In no event shall either Party, or their related companies be liable to each other for loss of profits or revenue; loss of use; loss of opportunity; loss of goodwill; cost of substitute facilities, goods or services; cost of capital; or for any special, consequential, incidental, or indirect, punitive, or exemplary damages resulting in any way from the performance of this Agreement, unless such damages are caused by a violation of the confidentiality provisions of this Agreement. For the avoidance of doubt, the foregoing shall not be construed to mean that Delta-T is not obligated to deliver the equipment it has agreed to provide to Client pursuant to the terms hereof.

Article 10 — Limitation of Liability

10.1 In no case shall Delta-T have any liability under this Agreement in excess of insured claims and amounts paid by Client hereunder.

Article 11 — Indemnification

11.1 Delta-T, to the fullest extent permitted by law, shall indemnify, defend and hold harmless Client, and its officers, directors, employees and agents from and against all claims, losses, damages, liabilities, including attorneys’ fees and expenses, for bodily injury, sickness or death, and property damage or destruction to the extent resulting from the acts, errors or omissions of any of Delta-T’s officers, agents, employees, Delta-T’s subcontractors or any other person for whose acts any of them may be liable, or for breach of this Agreement by Delta-T.

11.2 Client, to the fullest extent permitted by law, shall indemnify, defend and hold harmless each of Delta-T, officers, directors, employees and agents from and against claims, losses, damages, liabilities, including attorneys’ fees and expenses, for bodily injury, sickness or death, and property damage or destruction to the extent resulting from the acts, errors or omissions of Client, its officers, directors, employees, agents, and Client’s separate contractors or anyone for whose acts any of them may be liable, or for breach of this Agreement by Client.

Article 12 — Progress Updates

12.1 Delta-T shall provide Client with monthly, written updates during the term of this Agreement setting forth quantity and vendor information for equipment for which orders have been placed. Delta-T shall also provide Client with updates on any cancellation fees associated with purchased equipment.

Article 13 — Counterparts

13.1 This Agreement may be executed in any number of counterparts and by different parties hereto in separate counterparts, each of which when so executed and delivered shall be deemed an original, but all such counterparts together shall constitute but one and the same instrument.

13.2 This Agreement shall not be construed as creating a formal business entity of any kind, or as creating a joint venture, partnership, agency, fiduciary or employment relationship among the Parties. No Party shall have the authority or right, and no Party shall hold itself out as having the authority or right, to assume, create or undertake any obligation of any kind whatsoever, express or implied, on behalf of or in the name of another Party without the express written consent of such other Party.

IN WITNESS WHEREOF, the Parties hereto have executed this Agreement, effective as of the date first written above.

AVENTINE RENEWABLE ENERGY HOLDINGS, INC.

By:	/s/ Jeffrey A. Moery
Title:		VP Plant Construction


DELTA-T CORPORATION

By:	/s/ James T. Callahan
Title:		Chief Operating Officer


KIEWIT ENERGY COMPANY(1)

By:	/s/ Bradley J. Kaufman
Title:		President

(1) This Agreement is executed by Kiewit Energy Company (“Kiewit”) solely for the purposes of evidencing its agreement that, if an EPC Contract is duly negotiated and entered into between Kiewit and Client with respect to a Plant for which all or any portion of the Work hereunder pertains, Kiewit agrees that the payments made under this Agreement shall be credited to any applicable EPC Contract price and the provisions of the EPC Contract shall govern such Work, to the extent a design and procurement subcontract between Kiewit and Delta-T for such Plant is duly negotiated and entered into, and further provided that such credit and the provisions of the EPC Contract shall apply only to the extent of the Work applicable to the scope of such EPC Contract, as agreed by Client, Kiewit and Delta-T. Kiewit’s obligations under this Agreement are strictly limited to this acknowledgement, and Kiewit shall have no obligation to enter into an EPC Contract or any other agreement with Client or Delta-T, except to the extent it may do so in its own, sole discretion.

Exhibit A

The confidential information has been omitted and filed separately with the Securities and Exchange Commission.

Exhibit 10.2

AURORA PRE-EPC AGREEMENT

This AGREEMENT (“Agreement”) is made and entered into as of this 17th day of March, 2007, by and between Aventine Renewable Energy, Inc., a Delaware corporation (hereinafter “Owner”), and Kiewit Energy Company (hereinafter, “Consultant” or “EPC Contractor”). Owner, Consultant, and EPC Contractor may be individually referred to herein as “Party” and collectively as “Parties”.

Owner is developing a 113 denatured million gallon per year ethanol plant which is proposed to utilize Delta-T technology, in Aurora, Nebraska (the “Project”). Owner and Consultant are negotiating an Engineering, Procurement and Construction contract (the “Aurora EPC Contract”) pursuant to which Contractor would engineer and construct the Project. For the avoidance of doubt, neither Party shall be bound by or required to enter into the Aurora EPC Contract until the definitive Aurora EPC Contract has been agreed and fully executed by each Party.

However, to expedite the performance of certain tasks related to the design and construction of the Project, Owner desires to retain Consultant, and Consultant desires to be retained, to perform certain advance engineering, design, and construction services in connection with the Project, all as and to the extent described below.

1.0 Engagement of Services. Owner hereby retains Consultant to perform design, engineering, estimating, scheduling, and other professional services (“Services”) identified in Exhibit A (“Scope of Work”) attached hereto. The Services may be modified or amended from time to time upon mutual agreement of the Parties and may be described in one or more additional Exhibits. If such modifications or amendments necessitate an increase or decrease in either (a) the amount due or (b) the time required for performance, such matters shall be agreed upon in writing prior to proceeding with the change. No payment shall be made by Owner for any modification not so directed or authorized prior to proceeding with the modification. Consultant shall perform, or cause to be performed, all such Services in accordance with all applicable laws, rules and regulations and in accordance with good industry practices.

2.0 Compensation. In consideration for completion of the Services, Owner shall pay Consultant as specified in Section 3.0, the aggregate amount not to exceed Eleven Million Nine Hundred Eighty Six Thousand Seventy Eight Dollars ($11,986,078) (“Fee”). The Fee shall be increased or decreased according to modifications and amendments agreed to as provided herein.

3.0 Terms of Payment. Consultant shall invoice Owner on or about the thirtieth (30th) of each month, for hours actually worked, in accordance with Exhibit A. Owner shall pay Consultant the full amount of such invoice, on or before the fifteenth (15th) of the month following the period for which the invoice was provided.

4.0 Effective Date. This Agreement shall become effective upon the date of its execution.

5.0 Consultant an Independent Contractor. Consultant shall be an independent contractor with respect to the Services to be performed hereunder. Neither Contractor nor its subcontractors or vendors, nor the employees of either, shall be deemed to be the servants or employees of Owner.

6.0 Confidential Information. Confidential Information shall be governed by the confidentiality agreement currently in place between Owner and Consultant.

7.0 Survival. The rights and obligations contained in Section 6 (“Confidential Information”) shall survive any termination or expiration of this Agreement.

8.0 Successors and Assigns. Except as otherwise expressly stated herein, Consultant may not subcontract or otherwise delegate or assign its obligations under this Agreement to third parties (other than Consultant’s affiliates, which subcontracting, delegation and/or assignment to Consultant’s affiliates shall not relieve Consultant of its obligations hereunder) without Owner’s prior written consent. Subject to the foregoing, this Agreement shall be for the benefit of Owner’s successors and assigns, and shall be binding on Consultant’s assignees.

9.0 Notices. Any notice required or permitted by this Agreement shall be in writing and shall be delivered as follows with notice deemed given as indicated: (i) by personal delivery when delivered personally; (ii) by overnight courier upon written verification of receipt; (iii) by telecopy or facsimile transmission upon acknowledgment of receipt of electronic transmission; or (iv) by certified or registered mail, return receipt requested, upon verification of receipt. Notice shall be sent to the Parties at the addresses set forth below or such other address as either Party may specify in writing.

If to Owner:

Aventine Renewable Energy, Inc.
1300 South 2nd Street
Pekin, IL 61554
Phone: (309) 347 - 9714
Fax: (309) 478 - 1542
Attention: Jeffrey A. Moery

If to Consultant:

Kiewit Energy Company
7906 North Sam Houston Parkway West, Suite 300
Houston, TX 77064
Attn: Brad Kaufman
Phone: (281) 517-8900
Fax: (281) 517-8909

10.0 Governing Law. This Agreement shall be governed in all respects by the laws of the United States of America and by the laws of the State of New York (excluding New York’s body of law controlling conflicts of laws and excluding 5-323 of the New York General Obligations Law).

11.0 Severability. Should any provisions of this Agreement be held by a court of law to be illegal, invalid or unenforceable, the legality, validity and enforceability of the remaining provisions of this Agreement shall not be affected or impaired thereby.

12.0 Waiver. The waiver by either Party of any provision of this Agreement shall not operate to be construed as a waiver of any other provision by such Party.

13.0 Aurora EPC Contract. If and when a definitive Aurora EPC Contract is executed, the Services provided and payments made hereunder shall be considered to be work provided and advance payments under the Aurora EPC Contract. In addition, upon Owner’s release of the Notice to Proceed (NTP) under such Aurora EPC Contract, this Agreement shall automatically terminate in its entirety. In the event of such termination of this Agreement, the Aurora EPC Contract shall govern all Services previously performed and to have been performed, as well as all of the Parties rights and obligations with respect to such Services.

14.0 Third Party Guarantees. If any of the Services requires the purchase of equipment or materials or the procurement of services, Consultant shall, for the protection of Owner, demand from all vendors and subcontractors guarantees, warranties, indemnities and/or insurance coverage (collectively “Guarantees”) with respect to such equipment, materials and services, which shall be made available to Owner to the full extent of the terms thereof. Consultant’s liability with respect to such equipment and materials obtained from vendors or services from subcontractors shall, except for Consultant’s obligations to pay such vendors or subcontractors, be limited to procuring such Guarantees from such vendors or subcontractor and rendering all reasonable assistance to Owner as part of the Services for the purpose of enforcing the same, which may include, without limitation, enforcing such Guarantees, at Owner’s expense, if such Guarantees are not assignable to Owner.

15.0 Limitation of Liability. NEITHER OWNER NOR CONSULTANT NOR THEIR RESPECTIVE RELATED COMPANIES, AND SUBCONTRACTORS SHALL BE LIABLE FOR SPECIAL, INDIRECT OR CONSEQUENTIAL DAMAGES IN CONNECTION WITH THIS AGREEMENT. Consultant’s total liability to Owner for all claims, losses and damages resulting in any way from this Agreement and the performance of the Services shall not exceed the amount that Owner actually paid to Consultant under this Agreement. For the avoidance of doubt, the foregoing limitations of liability do not excuse Consultant’s obligation under the last sentence of Section 14 to render all reasonable assistance to Owner for the purpose of enforcing the Guarantees. The limitations, indemnities, waivers and release from liability expressed in this Agreement shall apply regardless of the basis of liability, including without limitation, contract, warranty, negligence or other fault, or strict liability; provided, however, such limitations and releases shall only be effective to the maximum extent allowed by law. Owner represents that, prior to commencement of any Services at a project site, it will obtain a release and waiver of damages in accordance with the foregoing from any affiliated company that owns or controls the project site. Owner and Consultant waive, and each shall cause its respective insurance carriers in Owner’s and Consultant’s

Corporate Excess Liability program, as applicable, to waive, all rights of subrogation against each other with respect to the insurance in such programs. If and when a definitive Aurora EPC Contract is executed, the definitive Aurora EPC Contract (or any relevant agreement executed in connection therewith) shall thereafter govern the Parties’ respective limitations on liabilities in connection with the Services and this Agreement.

16.0 Disputes. In the event of any litigation to enforce or interpret any terms or conditions of this Agreement, the Parties agree that such appropriate action shall be submitted to the jurisdiction of the federal or state courts located in Nebraska, to the exclusion of any and all other courts, forums, venues, and the Parties waive any and all right to contest the exclusivity of such forum, including any rights based upon the doctrine of forum non conveniens. In the event either Party institutes suit in court against the other Party or against the surety of such Party, in connection with any dispute or matter arising under this Agreement, the prevailing Party shall be entitled to recover all costs, expenses and attorneys’ fees, in addition to any other relief granted by the court or arbitrator(s). Both Parties hereby waive any and all rights to a trial by jury. In no event shall the litigation of any controversy or the settlement thereof delay the performance of this Agreement.

17.0 Records and Audits. Owner shall have the right to audit and inspect Consultant’s records and accounts covering costs hereunder and Services provided hereunder at all reasonable times during the course of the Services and for a period of twelve (12) months after completion of the Services; provided, however, the purpose of any such audit shall be only for verification of such costs and such Services. Consultant shall not be required to keep records of or provide access to costs covered by any fixed fee, unit rates or amounts expressed in terms of percentages of other costs.

18.0 Early Termination. Owner shall have the right to terminate this Agreement at any time upon prior written notice to Consultant. In the event of such termination, Owner shall pay Consultant for all Services performed and all payment obligations undertaken in Owner’s behalf, including breakage/cancellation charges required in subcontracts, prior to the date of such termination.

19.0 Entire Agreement. This Agreement constitutes the entire agreement between the Parties hereto and supersedes any oral or written representation, understandings, proposals, or communications heretofore entered into by or on account of the Parties with respect to the subject matter hereof and may not be changed, modified, or amended except in writing signed by the Parties hereto. The provisions of this Agreement are intended for the sole benefit of Consultant and Owner and their respective permitted successors and assigns, and each of Consultant’s subcontractors, vendors and others to the extent expressly provided in this Agreement.

20.0 Execution in Counterparts. This Agreement may be executed in two or more counterparts, each of which shall be deemed an original, but all of which together shall constitute one and the same instrument.

IN WITNESS WHEREOF, the Parties have executed this Agreement as of the date first written below.

“Owner”			“Consultant”

Aventine Renewable Inc.			Kiewit Energy Company

By:	/s/	Ronald H. Miller	By:	/s/	Bradley J. Kaufman

Name:		Ronald H. Miller	Name:		Brad Kaufman

Title:		President and CEO	Title:		President

Date:		3/17/07	Date:		3/12/07

Exhibit A

The confidential information has been omitted and filed separately with the Securities and Exchange Commission.

EXHIBIT 31.1

CHIEF EXECUTIVE OFFICER CERTIFICATION

I, Ronald H. Miller, certify that:

1. I have reviewed this quarterly report on Form 10-Q of Aventine Renewable Energy Holdings, 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(s) 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)) 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. 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

c. 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(s) 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 9, 2007

/s/ Ronald H. Miller
Ronald H. Miller
President, Chief Executive Officer
and Director

EXHIBIT 31.2

CHIEF FINANCIAL OFFICER CERTIFICATION

I, Ajay Sabherwal, certify that:

1. I have reviewed this quarterly report on Form 10-Q of Aventine Renewable Energy Holdings, Inc.;

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 9, 2007

/s/ Ajay Sabherwal
Ajay Sabherwal
Chief Financial Officer

EXHIBIT 32.1

CERTIFICATION 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 Aventine Renewable Energy Holdings, Inc. (the “Company”) on Form 10-Q for the period ending March 31, 2007 as filed with the Securities and Exchange Commission (the “Report”), I, Ronald H. Miller, Chief Executive Officer of Aventine Renewable Energy Holdings, Inc., certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that to the best of my knowledge and belief:

(1) The Report fully complies with the requirements of Section 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.

A signed original of this written statement required by Section 906 has been provided to Aventine Renewable Energy Holdings, Inc. and will be retained by Aventine Renewable Energy Holdings, Inc. and furnished to the Securities and Exchange Commission or its staff upon request.

	/s/ Ronald H. Miller
	Ronald H. Miller
	Chief Executive Officer
	May 9, 2007

EXHIBIT 32.2

CERTIFICATION 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 Aventine Renewable Holdings, Inc. (the “Company”) on Form 10-Q for the period ending March 31, 2007 as filed with the Securities and Exchange Commission (the “Report”), I, Ajay Sabherwal, Chief Financial Officer of Aventine Renewable Energy Holdings, Inc., certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that to the best of my knowledge and belief:

(1) The Report fully complies with the requirements of Section 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.

	/s/ Ajay Sabherwal
	Ajay Sabherwal
	Chief Financial Officer
	May 9, 2007