UNITED STATES
SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D.C. 20549

FORM 10-Q


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

For the quarterly period ended June 30, 2010


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 333-135729

ONE EARTH ENERGY, LLC

(Exact name of registrant as specified in its charter)


Illinois		20-3852246
(State or other jurisdiction of		(I.R.S. Employer
incorporation or organization)		Identification Number)

202 N. Jordan Drive, Gibson City, Illinois 60936
(Address of principal executive offices) (Zip Code)

(217) 784-5321
(Registrant’s telephone number, including area code)

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

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

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


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

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

At the close of business on November 12, 2010 the registrant had 13,781 membership units outstanding.

INDEX


	Page

PART I. FINANCIAL INFORMATION		3

Item 1. Financial Statements		3

Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations		14

Item 3. Quantitative and Qualitative Disclosures About Market Risk		18

Item 4. Controls and Procedures		19

PART II. OTHER INFORMATION		20

Item 1. Legal Proceedings		20

Item 1A. Risk Factors		20

Item 2. Unregistered Sales of Equity Securities and Use of Proceeds		20

Item 3. Defaults Upon Senior Securities		20

Item 4. Removed and Reserved		20

Item 5. Other Information		20

Item 6. Exhibits		21

SIGNATURES		21

Exhibit 31.1
Exhibit 31.2
Exhibit 32.1
Exhibit 32.2

PART I. FINANCIAL INFORMATION

Item 1. Financial Statements

ONE EARTH ENERGY, LLC
Condensed Balance Sheets
Unaudited


	June 30,		December 31,
	2010		2009
	(In Thousands)
Assets
Current assets:
Cash and cash equivalents	$	14,662	$	12,099
Accounts receivable, net		5,780		5,457
Inventory, net		5,161		6,290
Prepaid expenses		1,615		1,579
Other current assets		1,764		1,276

Total current assets		28,982		26,701
Property and equipment, net		144,163		148,709
Deferred financing costs, net		1,119		1,259
Restricted cash		20		20
Other assets		525		595

Total assets	$	174,809	$	177,284

Liabilities and equity:
Current liabilities:
Accounts payable, trade	$	1,915	$	1,016
Current portion of long-term debt		8,628		8,089
Accrued real estate taxes		1,438		1,930
Derivative financial instruments		1,900		1,413
Other current liabilities		1,385		1,332

Total current liabilities		15,266		13,780

Long-term liabilities:
Long-term debt		74,550		89,910
Derivative financial instruments		4,295		3,818

Total long-term liabilities		78,845		93,728

Commitments and contingencies
Equity:
Members’ capital (13,781 units issued and outstanding in 2010 and 2009)		65,215		65,215
Retained earnings		15,483		4,561

Total members’ equity		80,698		69,776

Total liabilities and equity	$	174,809	$	177,284

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

ONE EARTH ENERGY, LLC
Condensed Statements Of Operations
Unaudited


	Three Months Ended						Six Months Ended
	June 30,						June 30,
	2010			2009			2010			2009
	(In Thousands, Except Per Share Amounts)

Revenues	$	50,346		$	—		$	103,585		$	—
Cost of sales		43,672			472			88,336			606

Gross profit (loss)		6,674			(472	)		15,249			(606	)
Selling, general and administrative expenses		(284	)		(335	)		(578	)		(442	)

Operating income (loss)		6,390			(807	)		14,671			(1,048	)
Interest and other income		28			28			48			68
Interest expense		(703	)		(150	)		(1,424	)		(150	)
(Losses) gains on derivative financial instruments, net		(1,304	)		1,214			(2,373	)		1,061

Net income (loss)	$	4,411		$	285		$	10,922		$	(69	)


Weighted average units outstanding — basic and diluted		14			14			14			14


Basic and diluted net income (loss) per unit	$	315.07		$	20.36		$	780.14		$	(4.93	)

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

ONE EARTH ENERGY, LLC
Condensed Statements Of Cash Flows
Unaudited


	Six Months Ended
	June 30,
	2010			2009
	(In Thousands)
Cash flows from operating activities:
Net income (loss)	$	10,922		$	(69	)
Adjustments to reconcile net income (loss) to net cash provided by (used in) operating activities:
Depreciation and amortization		4,899			27
Derivative financial instruments		964			(1,062	)
Changes in assets and liabilities:
Accounts receivable		(323	)		(26	)
Inventory		1,129			(5,641	)
Other assets		(454	)		(1,638	)
Accounts payable, trade		899			1,108
Other liabilities		(439	)		469

Net cash provided by (used in) operating activities		17,597			(6,832	)

Cash flows from investing activities:
Capital expenditures		(213	)		(31,532	)
Restricted cash		—			(20	)

Net cash used in investing activities		(213	)		(31,552	)

Cash flows from financing activities:
Payments of long-term debt		(14,821	)		—
Proceeds from long-term debt		—			41,205

Net cash (used in) provided by financing activities		(14,821	)		41,205

Net increase in cash and cash equivalents		2,563			2,821
Cash and cash equivalents, beginning of period		12,099			16

Cash and cash equivalents, end of period	$	14,662		$	2,837

Non cash investing activities — Accrued capital expenditures	$	—		$	2,000

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

ONE EARTH ENERGY, LLC

NOTES TO UNAUDITED CONDENSED FINANCIAL STATEMENTS
June 30, 2010

Note 1. Condensed Financial Statements

The condensed financial statements included in this report have been prepared by the Company, without audit, pursuant to the rules and regulations of the Securities and Exchange Commission and include, in the opinion of management, all adjustments necessary to state fairly the information set forth therein. Any such adjustments were of a normal recurring nature. Certain information and footnote disclosures normally included in financial statements prepared in accordance with accounting principles generally accepted in the United States of America have been omitted pursuant to such rules and regulations, although the Company believes that the disclosures are adequate to make the information presented not misleading. Financial information as of December 31, 2009 included in these financial statements has been derived from the audited financial statements included in the Company’s Annual Report on Form 10-K for the year ended December 31, 2009. These unaudited condensed financial statements should be read in conjunction with the financial statements and the notes thereto included in the Company’s Annual Report on Form 10-K for the year ended December 31, 2009. The results of operations for the interim periods are not necessarily indicative of the results to be expected for the year.

Nature of Operations — One Earth Energy, LLC (“the Company”) was organized on November 28, 2005, as an Illinois limited liability company. The Company was formed with the intention of constructing, owning and operating an ethanol production facility located near Gibson City, Illinois with an annual nameplate capacity of 100 million gallons. The Company completed construction of its ethanol plant and emerged from the development stage during 2009 and commenced production operations during the third quarter of 2009. The Company operates in one reportable segment, alternative energy.

Note 2. Accounting Policies

The interim condensed financial statements have been prepared in accordance with the accounting policies described in the notes to the financial statements included in the Company’s 2009 Annual Report on Form 10-K. While management believes that the procedures followed in the preparation of interim financial information are reasonable, the accuracy of some estimated amounts is dependent upon facts that will exist or calculations that will be accomplished at fiscal year end. Examples of such estimates include the fair value of financial instruments, lower of cost or market inventory calculations and the reserve for bad debts. Any adjustments pursuant to such estimates during the quarter were of a normal recurring nature. Actual results could differ from those estimates.

Revenue Recognition

The Company recognizes sales from the production of ethanol and distillers grains when title transfers to customers, upon shipment from its plant. Shipping and handling charges to customers are included in revenues. Revenues by product are as follows (amounts in thousands):


	Quarter Ended		Six Months Ended
	June 30, 2010		June 30, 2010

Ethanol	$	41,486	$	85,884
Dried distillers grains		8,820		17,608
Wet distillers grains		40		93

Total	$	50,346	$	103,585

Cost of Sales

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

ONE EARTH ENERGY, LLC

NOTES TO UNAUDITED CONDENSED FINANCIAL STATEMENTS
June 30, 2010

Selling, General and Administrative Expenses

The Company includes non-production related costs such as professional fees and certain payroll in selling, general and administrative expenses.

Interest Cost

No interest was capitalized for the six months ended June 30, 2010. Interest expense of $150,000 for the six months ended June 30, 2009 is net of approximately $1,530,000 of interest capitalized. Cash paid for interest for the six months ended June 30, 2010 was approximately $1,519,000. No interest was paid for the six months ended June 30, 2009.

Financial Instruments

Forward grain purchase and ethanol and distiller grain sale contracts are accounted for under the “normal purchases and normal sales” scope exemption of Financial Accounting Standards Board (“FASB”) Accounting Standards Codification (“ASC”), Derivatives and Hedging, (“ASC 815”) because these arrangements are for purchases of grain that will be delivered in quantities expected to be used by the Company and sales of ethanol and distiller grain quantities expected to be produced by the Company over a reasonable period of time in the normal course of business. The Company uses derivative financial instruments to manage its balance of fixed and variable rate debt. The Company does not hold or issue derivative financial instruments for trading or speculative purposes. Interest rate swap agreements involve the exchange of fixed and variable rate interest payments and do not represent an actual exchange of the notional amounts between the parties. The swap agreements were not designated for hedge accounting pursuant to ASC 815. The interest rate swaps are recorded at their fair values and the changes in fair values are recorded as gain or loss on derivative financial instruments in the Condensed Statements of Operations. The Company paid settlements of interest rate swaps of approximately $1,409,000 and $0 for the six months ended June 30, 2010 and 2009, respectively.

Income Taxes

The Company is organized as a limited liability company. Based upon the Company’s filing elections with the Internal Revenue Service, this provides that in lieu of corporation income taxes, the members of the Company are to separately account for their proportionate share of the Company’s items of income, deductions, losses and credits. Therefore, these condensed financial statements do not include a provision for income taxes.

Inventories

Inventories are carried at the lower of cost or market on a first-in, first-out (“FIFO”) basis. Inventory includes direct production costs and certain overhead costs such as depreciation, property taxes and utilities related to producing ethanol and related by-products. Reserves are established for estimated net realizable value based primarily upon commodity prices. The components of inventory at June 30, 2010 and December 31, 2009 are as follows (amounts in thousands):


	June 30,		December 31,
	2010		2009

Ethanol and other finished goods, net	$	1,937	$	1,558
Work in process, net		1,209		1,235
Grain and other raw materials		2,015		3,497

Total	$	5,161	$	6,290

ONE EARTH ENERGY, LLC

NOTES TO UNAUDITED CONDENSED FINANCIAL STATEMENTS
June 30, 2010

Property and Equipment

Property and equipment is recorded at cost. Depreciation is computed using the straight-line method. Estimated useful lives are 15 to 40 years for buildings and improvements, and 3 to 20 years for fixtures and equipment.

In accordance with ASC 360-05, Impairment or Disposal of Long-Lived Assets, the carrying value of long-lived assets is assessed for recoverability by management when changes in circumstances indicate that the carrying amount may not be recoverable, based on an analysis of undiscounted future expected cash flows from the use and ultimate disposition of the asset. There were no impairment charges in the first six months of 2010 or 2009. Impairment charges result from the Company’s management performing cash flow analysis and represent management’s estimate of the excess of net book value over fair value. Fair value is estimated using expected future cash flows on a discounted basis or appraisals as appropriate. Long-lived assets are tested for recoverability whenever events or changes in circumstances indicate that its carrying amount may not be recoverable. Generally, declining cash flows from the Company’s ethanol plant is an indicator of possible impairment.

Deferred Financing Costs

Costs incurred in connection with the acquisition of financing for the construction of the ethanol plant were deferred and amortized over the term of the loan using the effective interest method. Accumulated amortization was approximately $279,000 and $140,000 at June 30, 2010 and December 31, 2009, respectively. Future amortization of deferred financing costs is as follows (amounts in thousands):


Years Ended December 31,	Amortization

Remainder of 2010	$	175
2011		286
2012		248
2013		213
2014		197

Total	$	1,119

Comprehensive Income (Loss)

For all periods presented, net income (loss) equals comprehensive income (loss) as the Company had no income or expense items that were not reported on the condensed statements of operations.

Accounting Changes and Recently Issued Accounting Standards

In June 2009, the FASB issued a new accounting standard that clarified how a company determines whether an entity, that is insufficiently capitalized or not controlled through voting (or similar rights), should be capitalized (ASC 810). This determination of whether a company is required to consolidate an entity is based on, among other things, an entity’s purpose and design and a company’s ability to direct the activities of the entity that most significantly impact the entity’s economic performance. This standard requires an ongoing reassessment of whether a company is the primary beneficiary of a variable interest entity. This standard also requires additional disclosures about a company’s involvement in variable interest entities and any significant changes in risk exposure due to that involvement. This standard is effective for fiscal years beginning after November 15, 2009. The Company adopted this standard as of January 1, 2010. This standard did not have any impact on the Company’s financial condition, results of operations or cash flows.

In January 2010, the FASB issued Accounting Standards Update (“ASU”) 2010-06, Fair Value Measurements and Disclosures (“ASU 2010-06”), which adds new disclosure requirements for transfers into and out of Levels 1 and 2 in the fair value hierarchy and additional disclosures about purchases, sales, issuances and settlements relating to Level 3 fair value measurements. This ASU also clarifies existing fair value disclosures about the level of disaggregation about inputs and valuation techniques used to measure fair value. The ASU was effective January 1, except for the requirement to provide the Level 3 activity on a gross basis, which is effective for fiscal years beginning after December 15, 2010 and interim periods within those years. This standard did not have any impact on the Company’s financial condition, results of operations or cash flows.

ONE EARTH ENERGY, LLC

NOTES TO UNAUDITED CONDENSED FINANCIAL STATEMENTS
June 30, 2010

Note 3. Members’ Equity

In February 2006, the Company raised $1,425,000 from five seed capital investors in exchange for 855 Class A units. The Company filed a Form SB-2 Registration Statement with the Securities and Exchange Commission (“SEC”). The original offering was for a minimum of 6,020 Class B units and up to 12,020 Class B units at $5,000 per unit for minimum offering proceeds of $30,100,000 and maximum offering proceeds of $60,100,000, before any costs of raising capital. The registration became effective November 7, 2006.

In June 2007, the Company filed an amendment to its Form SB-2 Registration Statement with the SEC. The new offering was for a minimum of 12,891 units and up to 14,000 units at $5,000 per unit for minimum offering proceeds of $64,455,000 and maximum offering proceeds of $70,000,000, before any costs of raising capital. As a result of the amendments to the amended and restated operating agreement as required by the Farmers Energy, Inc. (“Farmers Energy”), a subsidiary of REX American Resources Corporation, agreement (discussed below), the separate classes of units were eliminated and the Company now has one class of units.

In May 2007, the Company entered into an agreement with Farmers Energy, a subsidiary of REX American Resources Corporation, whereby Farmers Energy agreed to purchase a minimum of 7,011 units for a minimum purchase price of $35,055,000 and a maximum of 12,491 units for a maximum purchase price of $62,455,000. The actual number of units purchased by Farmers Energy was dependent upon the number and amount of rescissions resulting from a rescission offer, as described below, and the total number of new subscribers. Farmers Energy purchased 10,153 units from the Company. Farmers Energy has the right to appoint a majority of the board members of the Company and has the majority vote regardless of the number of board members.

In July 2007, The Company conducted a rescission offer with the current subscribers due to the Company changing the terms of the initial public offering. A total of 171 subscribers with 2,602 units chose to withdraw their subscriptions and have their deposits returned totaling $1,330,500, plus interest. On October 31, 2007, after meeting the terms of the escrow agreement, the Company terminated its escrow account and the offering proceeds were released to the Company. The Company closed the public offering on November 7, 2007. As of June 30, 2010, the Company had issued 13,781 units totaling $66,055,000 ($65,215,000 net of issuance costs). Through June 30, 2010, the Company had not made any distributions to members for income tax payments or other purposes.

Note 4. Property and Equipment

In May 2007, the Company entered into an agreement with Fagen, Inc. (“Fagen”), the designer/builder of the Company’s ethanol plant. Fagen was responsible for all engineering, labor, materials and equipment to design, construct, startup and achieve guaranteed performance criteria of the plant. The contract price was $120 million, subject to adjustments as provided by the general conditions of the agreement. Construction of the plant began in October 2007, and was substantially completed in July 2009. See Note 8 for a discussion of related-party transactions. The components of property and equipment at June 30, 2010 and December 31, 2009 are as follows (amounts in thousands):


	June 30,			December 31,
	2010			2009

Land and improvements	$	14,338		$	14,318
Machinery and equipment		117,529			117,442
Buildings and improvements		21,251			21,237
Furniture and fixtures		600			518
Construction in progress		35			24

Property and equipment, gross		153,753			153,539
Less: accumulated depreciation		(9,590	)		(4,830	)

Property and equipment, net	$	144,163		$	148,709

ONE EARTH ENERGY, LLC

NOTES TO UNAUDITED CONDENSED FINANCIAL STATEMENTS
June 30, 2010

Note 5. Long-Term Debt

In September 2007, the Company entered into a $111,000,000 financing agreement consisting of a construction loan agreement for $100,000,000 together with a $10,000,000 revolving loan and a $1,000,000 letter of credit with First National Bank of Omaha (the “Bank”). The construction loan was converted into a term loan on July 31, 2009, and bears interest at rates ranging from London InterBank Offered Rate (LIBOR), plus 300 basis points to LIBOR, plus 310 basis points. The term loan is secured by all of the Company’s assets. Pursuant to the terms of the loan agreement with the Bank, the Company has certain restrictions on its distributions to members based upon taxable income and net income in a given period. The Company’s restricted net assets total approximately $76.7 and $65.0 million at June 30, 2010 and December 31, 2009, respectively.

Beginning with the first quarterly payment on October 8, 2009, payments are due in 19 equal quarterly payments of principal and accrued interest, with the principal portion calculated based on a 120-month amortization schedule. One final installment will be required on the maturity date, July 8, 2014, for the remaining unpaid principal balance with accrued interest.

As of June 30, 2010, approximately $83.2 million was outstanding on the term loan. The Company is also subject to certain financial covenants under the loan agreement, including required levels of Earnings Before Interest, Taxes, Depreciation, and Amortization, debt service coverage ratio requirements, net worth requirements, and other common covenants. The Company was in compliance with all covenants at June 30, 2010.

The Company paid approximately $1,399,000 to the Bank and other parties since inception for various fees associated with the construction and term loan commitment. These amounts were recorded as prepaid loan fees by the Company in the accompanying balance sheets; such amounts are amortized using the effective interest method, beginning with the first payment on the term loan and ending with the term loan maturity date. The carrying values of the construction loan and term loan approximate fair value at June 30, 2010. In accordance with the agreement, the Company entered into an interest rate swap contract to minimize its interest risk exposure (see Note 5).

Annual expected maturities on notes payable at June 30, 2010, are as follows (amounts in thousands):


Years Ended December 31,	Maturities

Remainder of 2010	$	4,456
2011		9,639
2012		10,791
2013		11,229
2014		47,063

Total	$	83,178

The Company has no outstanding borrowings on the $10.0 million revolving loan at June 30, 2010. The Company has issued letters of credit that total $480,000 outstanding as of June 30, 2010.

ONE EARTH ENERGY, LLC

NOTES TO UNAUDITED CONDENSED FINANCIAL STATEMENTS
June 30, 2010

Note 6. Fair Value

Effective January 1, 2008, the Company adopted ASC 820 Fair Value Measurements and Disclosures (“ASC 820”), which provides a framework for measuring fair value under GAAP. This accounting standard defines fair value as the exchange price that would be received for an asset or paid to transfer a liability (an exit price) in the principal or most advantageous market for the asset or liability in an orderly transaction between market participants on the measurement date. ASC 820 also eliminated the deferral of gains and losses at inception of certain derivative contracts whose fair value was not evidenced by market observable data. ASC 820 requires that the impact of this change in accounting for derivative contracts be recorded as an adjustment to beginning retained earnings in the period of adoption. There was no impact on the beginning balance of retained earnings as a result of adopting ASC 820 because the Company held no financial instruments in which a gain or loss at inception was deferred.

Effective January 1, 2008, the Company determined the fair market values of its financial instruments based on the fair value hierarchy established by ASC 820. ASC 820 requires an entity to maximize the use of observable inputs and minimize the use of unobservable inputs when measuring fair value. The standard describes three levels of inputs that may be used to measure fair values which are provided below. The Company carries derivative liabilities at fair value.

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

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

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

The fair values of derivative assets and liabilities traded in the over-the-counter market are determined using quantitative models that require the use of multiple market inputs including interest rates, prices and indices to generate pricing and volatility factors, which are used to value the position. The predominance of market inputs are actively quoted and can be validated through external sources, including brokers, market transactions and third-party pricing services. Estimation risk is greater for derivative asset and liability positions that are either option-based or have longer maturity dates where observable market inputs are less readily available or are unobservable, in which case interest rate, price or index scenarios are extrapolated in order to determine the fair value. The fair values of derivative assets and liabilities include adjustments for market liquidity, counterparty credit quality, the Company’s own credit standing and other specific factors, where appropriate. To ensure the prudent application of estimates and management judgment in determining the fair value of derivative assets and liabilities, various processes and controls have been adopted, which include: model validation that requires a review and approval for pricing, financial statement fair value determination and risk quantification; periodic review and substantiation of profit and loss reporting for all derivative instruments. Financial assets and liabilities measured at fair value on a recurring basis at June 30, 2010 are summarized below (amounts in thousands):


	Level 1		Level 2		Level 3		Fair Value

Derivative liabilities	$	—	$	6,195	$	—	$	6,195

ONE EARTH ENERGY, LLC

NOTES TO UNAUDITED CONDENSED FINANCIAL STATEMENTS
June 30, 2010

Financial assets and liabilities measured at fair value on a recurring basis at December 31, 2009 are summarized below (amounts in thousands):


	Level 1		Level 2		Level 3		Fair Value

Derivative liabilities	$	—	$	5,231	$	—	$	5,231

Note 7. Financial Instruments

The Company uses derivative financial instruments to manage the balance of fixed- and variable-rate debt. The Company does not engage in trading activities involving derivative contracts for which a lack of marketplace quotations would necessitate the use of fair value estimation techniques. Interest rate swap agreements involve the exchange of fixed-rate and variable-rate interest payments and do not represent an actual exchange of the notional amounts between the parties. The swap agreements were not designated for hedge accounting pursuant to accounting standards.

The Company entered into two forward interest swaps with First National Bank of Omaha in the notional amounts of $50 million and $25 million. The swaps fixed the interest rate on $50 million and $25 million of the term loan at 7.9% and 5.49%, respectively. Swap settlements on the $50 million swap commenced as of July 31, 2009 and the termination date is July 8, 2014. Swap settlements on the $25 million swap commenced as of July 31, 2009 and the termination date is July 31, 2011.

As of June 30, 2010, and December 31, 2009, the notional values of the interest rate swaps were approximately $70.8 million and $73.5 million, respectively. At June 30, 2010 and December 31, 2009, the Company has recorded a liability of approximately $6.2 million and $5.2 million, respectively, related to the fair value of the swaps.

The notional amounts and fair values of derivatives, all of which are not designated as cash flow hedges at June 30, 2010 are summarized in the table below (amounts in thousands):


	Notional		Fair Value
	Amount		Liability

Interest rate swaps	$	70,846	$	6,195

As the interest rate swaps are not designated as cash flow hedges, the unrealized gain and loss on the derivatives is reported in current earnings as losses/gains on derivative financial instruments, net. The Company reported losses of approximately $1,304,000 and gains of $1,214,000 in the second quarters of 2010 and 2009, respectively. The Company reported losses of approximately $2,373,000 and gains of $1,061,000 in the first six months of 2010 and 2009, respectively. The Company paid settlements of interest rate swaps of approximately $1,409,000 during the first six months of 2010. There were no swap settlements during the first six months of 2009.

In the normal course of its ethanol business, the Company enters into forward pricing agreements for the purchase of grain and for the sale of ethanol and distillers grains for delivery in future periods. The Company accounts for these forward pricing arrangements under the “normal purchases and normal sales” scope exemption of ASC 815.

The Company has forward purchase contracts for 4.4 million bushels of corn, the principal raw material for its ethanol plant. The Company expects to take delivery of the corn through September 2010. The unrealized gain of such contracts was approximately $555,000 at June 30, 2010.

The Company has sales commitments for 10.4 million gallons of ethanol and 41,000 tons of distiller grains. The Company expects to deliver the ethanol and distiller grains through September 2010. The unrealized gain of such contracts was approximately $515,000 at June 30, 2010.

ONE EARTH ENERGY, LLC

NOTES TO UNAUDITED CONDENSED FINANCIAL STATEMENTS
June 30, 2010

Note 8. Related-Party Transactions

The Company entered into a design-build contract with Fagen, an equity investor in the Company, for the design and construction of the ethanol plant. Construction of the ethanol plant was completed in 2009; the Company has paid approximately $120.2 million at December 31, 2009, to Fagen.

During the second quarter and first six months of 2010, the Company purchased approximately $32.9 million and $65.4 million, respectively, of corn from the Alliance Grain Company, an equity investor.

During the second quarter and first six months of 2010, the Company used the services of the Bloomer Line to move railcars to ship ethanol. An officer of the Company is the acting general manager of the Bloomer Line. During the second quarter and first six months of 2010, the Company paid the Bloomer Line approximately $82,000 and $164,000, respectively, for such services.

Note 9. Commitments and Contingencies

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

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

Forward-Looking Statements

This Form 10-Q contains or may contain forward-looking statements as defined in the Private Securities Litigation Reform Act of 1995. Such statements can be identified by use of forward-looking terminology such as “may,” “expect,” “believe,” “estimate,” “anticipate” or “continue” or the negative thereof or other variations thereon or comparable terminology. Readers are cautioned that there are risks and uncertainties that could cause actual events or results to differ materially from those referred to in such forward-looking statements. These risks and uncertainties include the risk factors set forth from time to time in the Company’s filings with the Securities and Exchange Commission and include among other things: the impact of legislative changes, the price volatility and availability of corn, distiller grains, ethanol, gasoline and natural gas, the ethanol plant operating efficiently and according to forecasts and projections, changes in the national or regional economies, weather and the effects of terrorism or acts of war. The Company does not intend to update publicly any forward-looking statements except as required by law. Other factors that could cause actual results to differ materially from those in the forward-looking statements are set forth in Item 1A of the Company’s Annual Report on Form 10-K for the year ended December 31, 2009 (File No. 333-135729).

Critical Accounting Policies and Estimates

During the three months ended June 30, 2010, we did not change any of our critical accounting policies as disclosed in our 2009 Annual Report on Form 10-K as filed with the Securities and Exchange Commission on November 8, 2010. All other accounting policies used in preparing our interim fiscal 2010 Condensed Financial Statements are the same as those described in our Form 10-K.

Overview

One Earth Energy, LLC (referred to as “One Earth,” “we,” “us” or the “Company”) was formed on November 28, 2005. We were formed for the purpose of raising capital to develop, construct, own and operate a 100 million gallon per year ethanol plant in east central Illinois near Gibson City, Illinois. We began producing ethanol and distillers grains at the plant in July 2009.

Our operations are highly dependent on commodity prices, especially prices for corn, ethanol, distillers grains and natural gas. As a result of price volatility for these commodities, our operating results can fluctuate substantially. The price and availability of corn is subject to significant fluctuations depending upon a number of factors that affect commodity prices in general, including crop conditions, weather, federal policy and foreign trade. Because the market price of ethanol is not always directly related to corn prices, at times ethanol prices may lag movements in corn prices and, in an environment of higher corn prices, reduce the overall margin structure at the plant. As a result, at times, we may operate our plant at negative or marginally positive operating margins.

We expect our ethanol plant to produce approximately 2.8 gallons of denatured ethanol for each bushel of corn processed in the production cycle. We refer to the difference between the price per gallon of ethanol and the price per bushel of corn (divided by 2.8) as the “crush spread.” Should the crush spread decline, it is possible that our ethanol plant will generate operating results that do not provide adequate cash flows for sustained periods of time. In such cases, production at our ethanol plant may be reduced or stopped altogether in order to minimize costs.

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

Results of Operations

Comparison of Three Months and Six Months Ended June 30, 2010 and 2009

The following table summarizes certain operating data for the periods presented:


	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2010		2009		2010		2009

Average selling price per gallon of ethanol	$	1.57	$	—	$	1.64	$	—
Average selling price per ton of dried distiller grains	$	117.81	$	—	$	121.43	$	—
Average selling price per ton of wet distiller grains	$	30.14	$	—	$	26.79	$	—
Average cost per bushel of grain	$	3.54	$	—	$	3.59	$	—
Average cost of natural gas (per mmbtu)	$	4.32	$	—	$	4.89	$	—

Revenues in the second quarter of 2010 were $50.3 million. We had no sales in the second quarter of 2009 as we did not begin production operations until July 2009. For the second quarter of 2010, the average selling price per gallon of ethanol was $1.57 and our sales were based upon approximately 26.6 million gallons of ethanol. For the second quarter of 2010, the average selling price per ton of distillers grains was $117.81 and our sales were based upon approximately 78,000 tons of distillers grains.

Revenues in the first six months of 2010 were $103.6 million. We had no sales in the first six months of 2009 as we did not begin production operations until June 2009. For the first six months of 2010, the average selling price per gallon of ethanol was $1.64 and our sales were based upon approximately 52.5 million gallons of ethanol. For the first six months of 2010, the average selling price per ton of distillers grains was $121.43 and our sales were based upon approximately 151,700 tons of distillers grains.

We expect that revenues in future periods will be based upon production of approximately 100 million to 110 million gallons of ethanol and 300,000 to 320,000 tons of distillers grains per year. This expectation assumes that we will continue to operate at or near nameplate capacity, which is dependent upon the crush spread realized and other market conditions. The following table summarizes revenues by product group (amounts in thousands):


	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2010		2009		2010		2009

Ethanol	$	41,486	$	—	$	85,885	$	—
Dried distiller grains		8,820		—		17,608		—
Wet distiller grains		40		—		92		—

Total	$	50,346	$	—	$	103,585	$	—

Gross profit was approximately $6.7 million (13.3% of revenues) during the second quarter of 2010 compared to gross loss of $0.5 million during the second quarter of 2009. The gross loss in 2009 relates to certain expenses related to the production start up we were undergoing during 2009. Corn accounted for approximately 76% ($33.2 million) of our cost of sales during the second quarter of 2010. Natural gas accounted for approximately 8% ($3.3 million) of our cost of sales during the second quarter of 2010. Gross profit for the first six months of 2010 was $15.2 million (14.7% of revenues) which was approximately $15.8 million higher compared to gross loss of $0.6 million for the first six months of 2009. Corn accounted for approximately 76% ($67.0 million) of our cost of sales during the first six months of 2010. Natural gas accounted for approximately 9% ($7.5 million) of our cost of sales during the first six months of 2010. Given the inherent volatility in ethanol and corn prices, we cannot predict the likelihood that the spread between ethanol and grain prices, and the resulting gross profit or loss, in future periods will remain favorable or consistent compared to historical periods.

Selling, general and administrative expenses for the second quarter of 2010 were $0.3 million, consistent with the second quarter of 2009. Selling, general and administrative expenses were $0.6 million for the first six months of 2010 consistent with the first six months of 2009.

Interest and other income was $28,000 for the second quarter of 2010, consistent with the second quarter of 2009 results. Interest and other income of $48,000 for the first six months of 2010 was consistent with the first six months of 2009 results. We do not expect interest and other income to be significant in subsequent periods.

Interest expense was $0.7 million for the second quarter of 2010, an increase of $0.5 million over the prior year second quarter. Interest expense was $1.4 million for the first six months of 2010 compared to $0.2 million for the first six months of 2009, an increase of $1.2 million. The increases were primarily attributable to the higher amounts of average debt outstanding we had upon the completion of construction of our ethanol plant. In addition, we did not capitalize interest during 2010 as we did in 2009 while we were completing the construction of our ethanol plant. Based on current interest rates and debt levels, we expect interest expense in subsequent periods of 2010 to be consistent with the first and second quarters of 2010 results.

We recognized losses of $1.3 million and gains of $1.2 million during the second quarter of 2010 and 2009, respectively, related to forward starting interest rate swap agreements. We recognized a loss related to the swaps of approximately $2.4 million during the first six months of 2010 compared to gains of $1.1 million during the first six months of 2009. In general, declining interest rates in 2010 had a negative effect on our interest rate swaps as our swaps fixed the interest rate of variable rate debt. Should interest rates continue to decline, we would expect to experience continued losses on the interest rate swaps. We would expect to incur gains on the interest rate swaps should interest rates increase. We cannot predict the future movements in interest rates; thus, we are unable to predict the likelihood or amounts of future gains or losses related to interest rate swaps.

As a result of the foregoing, net income for the second quarter of 2010 was $4.4 million, an increase of $4.1 million from $0.3 million for the second quarter of 2009. Net income for the first six months of 2010 was $10.9 million, an increase of $11.0 million from net loss of $0.1 million for the first six months of 2009.

Trends and Uncertainties Impacting the Ethanol Industry and Our Operations

We are subject to industry-wide factors, trends and uncertainties that affect our operating and financial performance. These factors include, but are not limited to, the available supply and cost of corn from which our ethanol and distillers grains are processed; the cost of natural gas, which we use in the production process; new technology developments in the industry; dependence on our ethanol marketer and distillers grains marketer to market and distribute our products; the intensely competitive nature of the ethanol industry; and possible changes in legislation/regulations at the federal, state and/or local level. These factors as well as other trends and uncertainties are described in more detail below.

Economic Downturn

The U.S. stock markets crumbled during the winter of 2009 upon the collapse of multiple major financial institutions, the federal government’s takeover of two major mortgage companies, Freddie Mac and Fannie Mae, and the President’s enactment of a $700 billion bailout plan pursuant to which the federal government directly invested in troubled financial institutions. Financial institutions across the country have lost billions of dollars due to the extension of credit for the purchase and refinance of over-valued real property. The U.S. economy is in the midst of a recession, with increasing unemployment rates and decreasing retail sales. These factors have caused significant economic stress and upheaval in the financial and credit markets in the United States, as well as abroad. Credit markets have tightened and lending requirements have become more stringent. Oil prices and demand for fuel has fluctuated greatly and generally trended downward during our 2009 fiscal year. We believe that these factors have contributed to a decrease in the prices at which we are able to sell our ethanol which may persist throughout all or parts of fiscal year 2010.

Corn Prices

Our cost of goods sold consists primarily of costs relating to the corn and natural gas supplies necessary to produce ethanol and distillers grains for sale. On December 10, 2009, the USDA released its Crop Production report, which estimated the 2009 grain corn crop at approximately 12.9 billion bushels, approximately 7% higher than the USDA’s estimate of the 2008 corn crop of 12.1 billion bushels. Corn prices reached historical highs in June 2008, but have come down sharply since that time as stronger than expected corn yields materialized and the global financial crisis brought down the prices of most commodities generally. We expect continued volatility in the price of corn, which could significantly impact our cost of goods sold. The number of operating ethanol plants nationwide has declined over the past year due to the economic down turn and failed risk taking by some large competitors.

The price at which we will purchase corn depends on prevailing market prices. There is no assurance that a corn shortage will not develop, particularly if there is an extended drought or other production problems in the 2010 crop year. We anticipate that our plant’s profitability could be negatively impacted during periods of high corn prices that are not offset by increased ethanol prices. Although we expect the negative impact on profitability resulting from high corn prices to be mitigated, in part, by the increased value of the distillers grains we intend to market (as the price of corn and the price of distillers grains tend to fluctuate in tandem), we still may be unable to operate profitably if high corn prices are sustained for a significant period of time.

Ethanol Industry Competition

We operate in a competitive industry and compete with a number of larger ethanol producers. The significant economic down turn in the ethanol industry has driven many large and small producers out of the industry. The ethanol industry is starting to emerge from the difficult collapse that has occurred since the commencement of our operations in July 2009.

Distillers Grains Marketing

With the advancement of research into the feeding of distillers grains based rations to poultry, swine and beef, we anticipate these markets will continue to expand, creating additional demand for distillers grains.

Technology Developments

One current trend in ethanol production research is to develop an efficient method of producing ethanol from cellulose-based biomass, such as agricultural waste, forest residue, municipal solid waste, and energy crops. This trend is driven by the fact that cellulose-based biomass is generally cheaper than corn, and producing ethanol from cellulose-based biomass would create opportunities to produce ethanol in areas which are unable to grow corn. Although current technology is not sufficiently efficient to be competitive, the United States Congress is consistently increasing the availability of incentives to promote the development of commercially viable cellulose based ethanol production technology.

Advances and changes in the technology used to produce ethanol may make the technology we are installing in our plant less desirable or obsolete. As of this date, there are no known technologies that would cause our plant to become uncompetitive or completely obsolete.

Government Legislation and Regulations

The ethanol industry and our business are assisted by various federal ethanol supports and tax incentives, including those included in the Energy Policy Act of 2005 and the Energy Independence and Security Act of 2007. Government incentives for ethanol production, including federal tax incentives, may be reduced or eliminated in the future, which could hinder our ability to operate at a profit. Federal ethanol supports, such as the renewable fuels standard (“RFS”), help support a market for ethanol that might disappear without this incentive; as such, a waiver of minimum levels of renewable fuels included in gasoline could have a material adverse effect on our results of operations. The elimination or reduction of tax incentives to the ethanol industry, such as the VEETC available to gasoline refiners and blenders, could reduce the market for ethanol, causing prices, revenues, and profitability to decrease. VEETC is set to expire on December 31, 2010.

Liquidity and Capital Resources

Net cash provided by operating activities was approximately $17.6 million for the first six months of 2010, compared to cash used of $6.8 million for the first six months of 2009. For the first six months 2010, cash was provided by net income of $10.9 million, adjusted for non-cash items of $5.9 million, which consisted of depreciation and amortization and losses on derivative financial instruments. Inventory and accounts payable provided cash of $1.1 million and $0.9 million, respectively, a result of normal variations in production and sales levels. Accounts receivable used cash of $0.3 million, primarily a result of normal variations in sales levels and the timing of customer collections. Other assets used cash of $0.5 million, primarily a result of higher amounts of prepaid expenses and spare parts for operations.

Net cash used in operating activities was approximately $6.8 million for the first six months of 2009. For the first six months of 2009, cash was used by net loss of $0.1 million, net non-cash items of $1.0 million, which primarily consisted of depreciation and amortization and gains on derivative financial instruments. Inventory and other assets were the largest uses of cash as they used $5.6 million and $1.6 million, respectively. These uses of cash were primarily related to the start up of production operations in June and July of 2009. Accounts payable provided cash of $1.1 million also related to the start up of production operations in June and July of 2009.

At June 30, 2010, working capital was $13.7 million compared to $12.9 million at December 31, 2009. This increase is primarily a result of profitable operations during 2010 offset partially by repayments of long term debt. The ratio of current assets to current liabilities was 1.9 to 1 at June 30, 2010 and December 31, 2009.

Cash of $0.2 million was used in investing activities for the first six months of 2010, compared to $31.5 million of cash used during the first six months of 2009. Virtually all of the activities in this category of cash flows are capital expenditures, which, in the prior year relate to the construction of our ethanol plant, while current year capital expenditures were greatly reduced because we completed construction of our ethanol plant during 2009.

Cash used in financing activities totaled approximately $14.8 million for the first six months of 2010 compared to cash provided of $41.2 million for the first six months of 2009. Cash was used by debt payments of $14.8 million as the construction loan was converted to a term loan in 2009 once our ethanol plant construction was completed. During the first six months of 2009, we borrowed $41.2 million on our construction loan to fund construction related expenditures.

We will be constructing additional grain storage silos at our ethanol plant, expected to cost approximately $5 million. We expect to use existing cash on hand to pay for this project.

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

Item 3. Quantitative and Qualitative Disclosures About Market Risk

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

Interest Rate Risk

We are exposed to market risk from changes in interest rates. Exposure to interest rate risk results primarily from holding term and revolving loans that bear variable interest rates. Specifically, we have approximately $83.2 million outstanding in debt as of June 30, 2010, all of which is variable-rate. Interest rates on our variable-rate debt are determined based upon the market interest rate of LIBOR plus 300 to 310 basis points. A 10% adverse change (for example from 4.0% to 4.4%) in market interest rates would affect our interest cost on such debt by approximately $0.3 million per year in the aggregate.

We entered into two forward interest rate swaps in the notional amounts of $50.0 million and $25.0 million with the First National Bank of Omaha during the fiscal years ended December 31, 2008 and 2007. The $50.0 million swap fixed the variable interest rate of a portion of our term loan at 7.9%, while the $25.0 million swap fixed the variable interest rate of a portion of our term loan at 5.49%. The swap settlements commenced on July 31, 2009; the $50.0 million swap terminates on July 8, 2014 and the $25.0 million swap terminates on July 31, 2011. A hypothetical 10% change (for example, from 4.0% to 3.6%) in market interest rates at June 30, 2010 would change the fair value of the interest rate swaps by approximately $0.6 million.

Commodity Price Risk

We do not employ derivative instruments such as futures and options to hedge our commodity price risk. Our strategy is to “flat price” a portion of our electricity and natural gas requirements, and to purchase the remainder at current market prices. We purchase all of our corn through Alliance Grain.

A sensitivity analysis has been prepared to estimate our exposure to ethanol, corn and natural gas price risk. Market risk related to these factors is estimated as the potential change in income resulting from a hypothetical 10% adverse change in the fair value of our corn and natural gas prices and average ethanol price as of June 30, 2010. The volumes are based on our actual use and sale of these commodities for the quarter and six months ended June 30, 2010. The results of this analysis are as follows:


							Approximate
				Hypothetical			Adverse
	Volume for the quarter			Adverse Change			Change to
	ended June 30, 2010		Unit of Measure	in Price			Income
Natural Gas		750,087	MMBtu		10	%	$	324,000
Ethanol		26,578,135	Gallons		10	%	$	4,148,000
Corn		9,441,102	Bushels		10	%	$	3,318,000

							Approximate
				Hypothetical			Adverse
	Volume for the six months			Adverse Change			Change to
	ended June 30, 2010		Unit of Measure	in Price			Income
Natural Gas		1,514,847	MMBtu		10	%	$	740,000
Ethanol		52,524,774	Gallons		10	%	$	8,597,000
Corn		18,823,728	Bushels		10	%	$	6,701,000

Item 4. Controls and Procedures

Our management evaluated, with the participation of our President and Chief Financial Officer, the effectiveness of our disclosure controls and procedures, as of the end of the period covered by this report. Based on that evaluation, the President and Chief Financial Officer concluded that our disclosure controls and procedures are not effective to ensure that information required to be disclosed by us in the reports that we file or submit under the Securities Exchange Act of 1934 is recorded, processed, summarized and reported within the time periods specified in the Securities and Exchange Commission’s rules and forms and is accumulated and communicated to our management, including our President and Chief Financial Officer, as appropriate, to allow timely decisions regarding required disclosure because:

	•		Our disclosure controls and procedures did not adequately ensure the timely filing of our periodic reports on Form 10-Q for the quarters ended March 31, 2010 and June 30, 2010.

	•		We had a material weakness in our internal control over financial reporting with respect to our controls over reconciliation of member share counts, as disclosed in our 2009 Annual Report on Form 10-K as filed with the Securities and Exchange Commission on November 8, 2010.

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

PART II. OTHER INFORMATION

Item 1. Legal Proceedings

None.

Item 1A. Risk Factors

During the quarter ended June 30, 2010, there have been no material changes to the risk factors discussed in our Annual Report on Form 10-K for the year ended December 31, 2009.

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

During the quarter ended June 30, 2010, there have been no unregistered sales of membership units.

Dividend Policy

We did not pay dividends in the current or prior years. We currently have restrictions that limit the payment of dividends.

Item 3. Defaults Upon Senior Securities

None

Item 4. Removed and Reserved

Item 5. Other Information

None

Item 6. Exhibits

The following exhibits are filed with this report:


31.1	Certificate Pursuant to 17 CFR 240.13a-14(a)	*

31.2	Certificate Pursuant to 17 CFR 240.13a-14(a)	*

32.1	Certificate Pursuant to 18 U.S.C. § 1350	*

32.2	Certificate Pursuant to 18 U.S.C. § 1350.	*


(*)		Filed herewith.

SIGNATURES

In accordance with Section 13 or 15(d) of the Exchange Act, the registrant caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.


		ONE EARTH ENERGY, LLC

Date: November 15, 2010		/s/ Steven Kelly Steven Kelly
		President (Principal Executive Officer)

Date: November 15, 2010		/s/ Larry Brees Larry Brees
		Chief Financial Officer
		(Principal Financial and Accounting Officer)

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ONE EARTH ENERGY LLC 10-Q