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Table of Contents

 

 

 

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 June 30, 2010

 

OR

 

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

 

For the transition period from           to          .

 

Commission File Number: 000-53202

 

HOMELAND ENERGY SOLUTIONS, LLC

(Exact name of registrant as specified in its charter)

 

Iowa

 

20-3919356

(State or other jurisdiction of
incorporation or organization)

 

(I.R.S. Employer Identification No.)

 

2779 Highway 24, Lawler, Iowa, 52154

(Address of principal executive offices)

 

(563) 238-5555

(Registrant’s telephone number, including area code)

 

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

 

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files).   o  Yes   o  No

 

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

 

Large Accelerated Filer ¨

 

Accelerated Filer o

 

 

 

Non-Accelerated Filer ¨

 

Smaller Reporting Company x

 

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

 

Indicate the number of shares outstanding of each of the issuer’s classes of common stock, as of the latest practicable date:  As of August 13, 2010, there were 91,445 units outstanding.

 

 

 


 



Table of Contents

 

PART I.     FINANCIAL INFORMATION

Item 1.  Financial Statements

 

Homeland Energy Solutions, LLC

 

Balance Sheets

June 30, 2010 and December 31, 2009

 

 

 

June 30, 2010

 

December 31, 2009

 

 

 

Unaudited

 

 

 

ASSETS

 

 

 

 

 

 

 

 

 

 

 

CURRENT ASSETS

 

 

 

 

 

Cash and cash equivalents

 

$

9,727,848

 

$

832,040

 

Accounts Receivable

 

5,068,407

 

9,347,223

 

Inventory

 

6,198,499

 

6,273,488

 

Due from broker

 

 

870,059

 

Derivative instruments

 

31,863

 

 

Prepaid expenses

 

1,112,296

 

1,889,834

 

Other current assets

 

942,216

 

599,134

 

Total current assets

 

23,081,129

 

19,811,778

 

 

 

 

 

 

 

PROPERTY AND EQUIPMENT

 

 

 

 

 

Land and improvements

 

22,471,580

 

22,471,580

 

Buildings

 

4,870,412

 

4,863,070

 

Equipment

 

129,764,896

 

129,209,097

 

Construction in progress

 

1,604,142

 

1,230,695

 

 

 

158,711,030

 

157,774,442

 

Less accumulated depreciation

 

14,460,199

 

8,667,290

 

Total property and equipment

 

144,250,831

 

149,107,152

 

 

 

 

 

 

 

OTHER ASSETS

 

 

 

 

 

Loan fees, net of amortization 2010 $494,767; 2009 $406,305

 

678,205

 

766,667

 

Restricted cash

 

10,326,527

 

10,256,026

 

Utility rights, net of amortization 2010 $297,688; 2009 $184,293

 

2,064,670

 

2,578,065

 

Total other assets

 

13,069,402

 

13,600,758

 

 

 

 

 

 

 

TOTAL ASSETS

 

$

180,401,362

 

$

182,519,688

 

 

 

 

 

 

 

LIABILITIES AND MEMBERS’ EQUITY

 

 

 

 

 

 

 

 

 

 

 

CURRENT LIABILITIES

 

 

 

 

 

Accounts payable and accrued expenses

 

$

3,641,526

 

$

5,619,270

 

Derivative instruments

 

 

238,125

 

Due to Broker

 

39,730

 

 

Current maturities of long-term debt

 

7,412,141

 

6,795,116

 

Total current liabilities

 

11,093,397

 

12,652,511

 

 

 

 

 

 

 

COMMITMENTS AND CONTINGENCIES

 

 

 

 

 

 

 

 

 

 

 

LONG-TERM DEBT, less current maturities

 

53,557,751

 

62,263,911

 

 

 

 

 

 

 

MEMBERS’ EQUITY

 

 

 

 

 

Capital units, less syndication and offering costs

 

89,572,744

 

89,572,744

 

Retained earnings

 

26,177,470

 

18,030,522

 

Total members’ equity

 

115,750,214

 

107,603,266

 

 

 

 

 

 

 

TOTAL LIABILITIES AND MEMBERS’ EQUITY

 

$

180,401,362

 

$

182,519,688

 

 

See Notes to Unaudited Financial Statements.

 

3



Table of Contents

 

Homeland Energy Solutions, LLC

Statements of Operations (Unaudited)

 

 

 

Three Months

 

Three Months

 

Six Months

 

Six Months

 

 

 

Ended 6/30/10

 

Ended 6/30/09

 

Ended 6/30/10

 

Ended 6/30/09

 

 

 

 

 

 

 

 

 

 

 

REVENUE, NET OF SHIPPING COSTS

 

$

55,629,916

 

$

39,562,718

 

$

112,643,402

 

$

39,562,718

 

 

 

 

 

 

 

 

 

 

 

COSTS OF GOODS SOLD

 

52,519,070

 

38,133,578

 

102,356,914

 

38,133,578

 

 

 

 

 

 

 

 

 

 

 

GROSS PROFIT

 

3,110,846

 

1,429,140

 

10,286,488

 

1,429,140

 

 

 

 

 

 

 

 

 

 

 

SELLING, GENERAL AND ADMINISTRATIVE EXPENSES

 

564,278

 

150,199

 

1,134,895

 

1,366,736

 

 

 

 

 

 

 

 

 

 

 

OPERATING INCOME

 

2,546,568

 

1,278,941

 

9,151,593

 

62,404

 

 

 

 

 

 

 

 

 

 

 

OTHER INCOME (EXPENSE)

 

 

 

 

 

 

 

 

 

Interest expense

 

(536,271

)

(594,198

)

(1,131,967

)

(594,198

)

Interest income

 

60,589

 

61,591

 

127,322

 

139,148

 

Grant income

 

 

300,000

 

 

300,000

 

 

 

(475,682

)

(232,607

)

(1,004,645

)

(155,050

)

 

 

 

 

 

 

 

 

 

 

Net income (loss)

 

$

2,070,886

 

$

1,046,334

 

$

8,146,948

 

$

(92,646

)

 

 

 

 

 

 

 

 

 

 

Basic & diluted net income (loss) per unit

 

$

22.65

 

$

11.44

 

$

89.09

 

$

(1.01

)

 

 

 

 

 

 

 

 

 

 

Weighted average of units outstanding for the calculation of basic & diluted net income per unit

 

91,445

 

91,445

 

91,445

 

91,445

 

 

See Notes to Unaudited Financial Statements.

 

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Table of Contents

 

Homeland Energy Solutions, LLC

 

Statements of Cash Flows (Unaudited)

 

 

 

Six Months

 

Six Months

 

 

 

Ended June 30,

 

Ended June 30,

 

 

 

2010

 

2009

 

 

 

 

 

 

 

CASH FLOWS FROM OPERATING ACTIVITIES

 

 

 

 

 

Net income (loss)

 

$

8,146,948

 

$

(92,646

)

Adjustments to reconcile net income (loss) to net cash provided by (used in) operating activities:

 

 

 

 

 

Depreciation and amortization

 

5,994,766

 

2,972,052

 

Unrealized (gain) on derivatives

 

(269,988

)

(615,362

)

Asset impairment

 

 

480,875

 

Change in working capital components:

 

 

 

 

 

Accounts receivable

 

4,278,816

 

(6,174,895

)

Inventory

 

74,989

 

(5,928,852

)

Due to (from) broker

 

909,789

 

(613,112

)

Prepaid expenses and other assets

 

434,456

 

(1,542,445

)

Accounts payable and accrued expenses

 

(977,038

)

2,221,550

 

Net cash provided by (used in) operating activities

 

18,592,738

 

(9,292,835

)

 

 

 

 

 

 

CASH FLOWS FROM INVESTING ACTIVITIES

 

 

 

 

 

Refund of (payment for) utility rights

 

400,000

 

(400,000

)

Payments for equipment and construction in progress

 

(1,937,294

)

(25,419,970

)

Net cash (used in) investing activities

 

(1,537,294

)

(25,819,970

)

 

 

 

 

 

 

CASH FLOWS FROM FINANCING ACTIVITIES

 

 

 

 

 

Increase in outstanding checks in excess of bank balance

 

 

213,034

 

(Increase) in restricted cash

 

(70,501

)

(126,437

)

Proceeds from long-term borrowing

 

 

41,223,898

 

Payments on long-term borrowing

 

(8,089,135

)

(180,000

)

Net cash provided by (used in) financing activities

 

(8,159,636

)

41,130,495

 

 

 

 

 

 

 

Net increase in cash

 

$

8,895,808

 

$

5,804,656

 

 

 

 

 

 

 

CASH AND CASH EQUIVALENTS

 

 

 

 

 

Beginning

 

832,040

 

44,599

 

Ending

 

$

9,727,848

 

$

5,849,255

 

 

 

 

 

 

 

SUPPLEMENTAL DISCLOSURES OF CASH FLOW INFORMATION

 

 

 

 

 

Cash paid for interest

 

$

1,175,551

 

$

1,113,290

 

 

 

 

 

 

 

SUPPLEMENTAL SCHEDULE OF NONCASH INVESTING AND FINANCING ACTIVITIES

 

 

 

 

 

Accounts payable related to construction in progress

 

$

 

$

2,417,559

 

Retainage payable related to construction in progress

 

 

238,125

 

Interest capitalized

 

 

817,183

 

Insurance costs capitalized

 

 

83,423

 

Loan fee amortization capitalized

 

 

58,974

 

 

See Notes to Unaudited Financial Statements.

 

5


 


Table of Contents

 

HOMELAND ENERGY SOLUTIONS, LLC

Notes to Condensed Unaudited Financial Statements

 

June 30, 2010

 

1.              NATURE OF BUSINESS AND SIGNIFICANT ACCOUNTING POLICIES

 

Nature of business:  Homeland Energy Solutions, LLC (an Iowa Limited Liability Company) is located near Lawler, Iowa and was organized to pool investors for a 100 million gallon ethanol plant with distribution throughout the United States.  In addition, the company produces and sells distillers dried grains as byproducts of ethanol production.  Site preparation was completed and construction began in November 2007.  Prior to commencing operations on April 4, 2009, the Company was a development stage entity with its efforts being principally devoted to organizational activities and construction activities.

 

Significant Accounting Policies:

 

Basis of Presentation:  The accompanying unaudited condensed financial statements have been prepared pursuant to the rules and regulations of the Securities and Exchange Commission.  Certain information and footnote disclosures normally included in annual financial statements prepared in accordance with accounting principles generally accepted in the United States of America have been condensed or omitted as permitted by such rules and regulations.  These financial statements and related notes should be read in conjunction with the financial statements and notes thereto included in the company’s audited financial statements for the year ended December 31, 2009, contained in the Company’s annual report on Form 10-K for 2009.  In the opinion of management, the interim condensed financial statements reflect all adjustments considered necessary for fair presentation.  The adjustments made to these statements consist only of normal recurring adjustments.

 

Accounting Estimates:  Management uses estimates and assumptions in preparing these financial statements in accordance with United States Generally Accepted Accounting Principles.  Those estimates and assumptions affect the reported amounts of assets and liabilities, the disclosure of contingent assets and liabilities, and the reported revenues and expenses.  Actual results could differ from those estimates.

 

Revenue Recognition: Revenue from the sale of the Company’s products is recognized at the time title to the goods and all risks of ownership transfer to the customers.  This generally occurs upon shipment, loading of the goods or when the customer picks up the goods. Interest income is recognized as earned.  Shipping costs incurred by the Company in the sale of ethanol and distiller grains are not specifically identifiable and as a result, revenue from the sale of ethanol and distiller grains is recorded based on the net selling price reported to the Company from the marketer.

 

Inventories:  Inventories are generally valued at the lower of cost (first-in, first-out) or market.  In the valuation of inventories and purchase and sale commitments, market is based on current replacement values except that it does not exceed net realizable values and is not less than net realizable values reduced by allowances for approximate normal profit margin.

 

Long-Lived Assets: The Company reviews its property and equipment for impairment whenever events indicate that the carrying amount of the assets may not be recoverable.  If circumstances require a long-lived asset be tested for possible impairment, the Company first compares undiscounted cash flows expected to be generated by an asset to the carrying value of the asset. If the carrying value of the long-lived asset is not recoverable on an undiscounted cash flow basis, an impairment is recognized to the extent that the carrying value exceeds its fair value. Fair value is determined through various valuation techniques including discounted cash flow models, quoted market values and third-party independent appraisals, as considered necessary.

 

Derivative Instruments: The Company evaluates its contracts to determine whether the contracts are derivative instruments.  Certain contracts that literally meet the definition of a derivative may be exempted from derivative accounting as normal purchases or normal sales.  Normal purchases and normal sales are contracts that provide for the purchase or sale of something other than a financial instrument or derivative instrument that will be delivered in quantities expected to be used or sold over a reasonable period in the normal course of business.  Contracts that meet the requirements of normal purchases or sales are documented as normal and exempted from the accounting and reporting requirements of derivative accounting.

 

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Table of Contents

 

HOMELAND ENERGY SOLUTIONS, LLC

Notes to Condensed Unaudited Financial Statements

 

June 30, 2010

 

The Company enters into short-term cash, option and futures contracts as a means of securing purchases of corn, natural gas and sales of ethanol for the plant and managing exposure to changes in commodity and energy prices.  All of the Company’s derivatives are designated as non-hedge derivatives for accounting purposes, with changes in fair value recognized in net income.  Although the contracts are economic hedges of specified risks, they are not designated as and accounted for as hedging instruments.

 

As part of its trading activity, the Company uses futures and option contracts through regulated commodity exchanges to manage its risk related to pricing of inventories.  To reduce that risk, the Company generally takes positions using cash and futures contracts and options.

 

Realized and unrealized gains and losses related to derivative contracts related to corn and natural gas are included as a component of cost of goods sold and derivative contracts related to ethanol are included as a component of revenues in the accompanying financial statements.  The fair values of contracts entered through commodity exchanges are presented on the accompanying balance sheet as derivative instruments.

 

Intangible Assets:  Intangible assets consist of loan fees and utility rights.  Utility rights consist of payments to electric and natural gas companies for construction in aid of electric and gas lines to the facility but the Company retains no ownership rights to the assets.  The loan fees are amortized over the term of the loan and utility rights are amortized over 15 years or the anticipated useful life utilizing the effective interest method and straight-line method, respectively. The useful life was determined in part by the length of service agreements the Company has with the utility companies as well as normal usage of such infrastructure.

 

Restricted Cash:  The Company has a restriction on a specific account with a bank that is restricted in use for the repayment of long-term debt.  The balance in this account has been treated as a non-current asset due to this restriction.

 

Net Income (Loss) per Unit:  Basic and diluted net income per unit is computed by dividing net income by the weighted average number of members’ units and members’ unit equivalents outstanding during the period. There were no member unit equivalents outstanding during the periods presented; accordingly, the Company’s basic and diluted net income (loss) per unit are the same.

 

Risks and Uncertainties:  The Company has certain risks and uncertainties that it will experience during volatile market conditions, which can have a severe impact on operations.  The Company’s revenues are derived from the sale and distribution of ethanol and distiller grains to customers primarily located in the United States. Corn for the production process is supplied to the plant primarily from local agricultural producers and from purchases on the open market. Ethanol sales average approximately 84% of total revenues, while approximately 16% of revenues is generated from the sale of distiller grains and other by-products.  Corn costs average approximately 70% of cost of revenues.

 

The Company’s operating and financial performance is largely driven by the prices at which we sell ethanol and the net expense of corn. The price of ethanol is influenced by factors such as supply and demand, weather, government policies and programs, and unleaded gasoline and the petroleum markets, although since 2005 the prices of ethanol and gasoline began a divergence with ethanol selling for less than gasoline at the wholesale level. Excess ethanol supply in the market, in particular, puts downward pressure on the price of ethanol. Our largest cost of production is corn. The cost of corn is generally impacted by factors such as supply and demand, weather, government policies and programs, and our risk management program used to protect against the price volatility of these commodities.

 

The current U.S. economic condition has reduced the nation’s demand for energy.  In addition, the VEETC credit of $0.45 is set to expire in December 2010, creating additional uncertainty to the future of ethanol production.  The ethanol boom of recent years has spurred overcapacity in the industry and production capacity is currently exceeding the RFS mandates.  As such, the Company may need to evaluate whether crush margins will be sufficient to operate the plant and generate enough debt service.  In the event crush margins become negative for an extended period of time, the Company may be required to reduce capacity or shut down the plant.  The

 

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Table of Contents

 

HOMELAND ENERGY SOLUTIONS, LLC

Notes to Condensed Unaudited Financial Statements

 

June 30, 2010

 

Company will continue to evaluate crush margins on a regular basis.  Based on the Company’s operating plan and the borrowing capacity, management believes it has the capital to meet its obligations throughout the next twelve month period.

 

2.              INVENTORY

 

Inventory consisted of the following as of June 30, 2010 and December 31, 2009.

 

 

 

June 30, 2010

 

December 31, 2009

 

Raw Materials

 

$

2,727,605

 

$

3,152,894

 

Work in Process

 

1,095,376

 

1,191,732

 

Finished Goods

 

2,375,518

 

1,928,862

 

Totals

 

$

6,198,499

 

$

6,273,488

 

 

3.              DEBT

 

Master Loan Agreement with Home Federal Savings Bank

 

On November 30, 2007, the Company entered into a Master Loan Agreement with Home Federal Savings Bank (“Home Federal”) establishing a senior credit facility with Home Federal for the construction of a 100 million gallon per year natural gas powered dry mill ethanol plant.  In return, the Company executed a mortgage in favor of Home Federal creating a senior lien on the real estate and plant and a security interest in all personal property located on Company property.  The Master Loan Agreement provides for (i) a construction loan in an amount not to exceed $94,000,000 (of which up to $20,000,000 may be converted to a term revolving loan upon start-up of operations), and (ii)  a revolving line of credit loan in an amount not to exceed $6,000,000 (the foregoing collectively referred to as the “Loans”).

 

On July 1, 2009 the Company converted the $94,000,000 construction loan with Home Federal Savings Bank into a $74,000,000 term loan and a $20,000,000 term revolving loan under the terms of the Master Loan Agreement and supplements thereto.  The Company made monthly payments of accrued interest on the Term Loan from the date of conversion until seven months later.  Beginning in the seventh month after conversion, or on February 1, 2010, equal monthly principal payments in the amount of $616,667 plus accrued interest will be made.  All unpaid principal and accrued interest on the term loan will be due on the fifth anniversary of such conversion.  The Company will have the right to convert up to 50% of the term loan into a Fixed Rate Loan with the consent of Home Federal.  The Fixed Rate Loan will bear interest at the five year LIBOR swap rate that is in effect on the date of conversion plus 300 basis points, or another rate mutually agreed upon by Homeland Energy and Home Federal.  If the Company elects this fixed rate option, the interest rate will not be subject to any adjustments otherwise provided for in the Master Loan Agreement.  The remaining portion will bear interest at a rate equal to the LIBOR Rate plus 300 basis points.

 

The Company agreed to the terms of a $20,000,000 Term Revolving Loan which was converted on July 1, 2009 from the construction loan and has a maturity date of five years from the conversion date or July 2014.  Interest on the Revolving Term Loan shall accrue at a rate equal to the LIBOR Rate plus 300 basis points.  The Company will be required to make monthly payments of interest until the maturity date of July 2014, on which date the unpaid principal amount of the Revolving Term Loan will become due and payable.

 

Revolving Line of Credit Loan

 

Under the terms of the Master Loan Agreement and the third supplement thereto, the Company agreed to the terms of a Revolving Line of Credit Loan consisting of a maximum $6,000,000 revolving line of credit.  The Revolving Line of Credit Loan became available on July 1, 2009 when all conditions precedent to the Revolving Line of Credit Loan were met. The aggregate principal amount of the Revolving Line of Credit Loan may not exceed the lesser of $6,000,000 or the Borrowing Base.  The Borrowing Base means, at any time, the lesser of: (a) $6,000,000; or (b) the sum of (i) 75% of the eligible accounts receivable, plus (ii) 75% of the eligible inventory.  Interest on the Revolving

 

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Table of Contents

 

HOMELAND ENERGY SOLUTIONS, LLC

Notes to Condensed Unaudited Financial Statements

 

June 30, 2010

 

Line of Credit Loan shall accrue at a rate equal to the LIBOR Rate plus 300 basis points.  The Company was required to make monthly payments of accrued interest until the Revolving Line of Credit Loan expired on June 30, 2010.  This line of credit was not renewed.

 

If the Company fails to make a payment of principal or interest on any loan within 10 days of the due date, there will be a late charge equal to 5% of the amount of the payment.  Balances outstanding on the term loan, term revolving loan and revolving line of credit as of June 30, 2010 and December 31, 2009, were $60,916,667, $0 and $0, and $69,000,000, $0 and $0, respectively. Amounts available on the term loan, term revolving loan and revolving line of credit as of June 30, 2010 were $0, $20,000,000 and $6,000,000, respectively.

 

Covenants

 

In addition, during the term of the loans, the Company will be subject to certain financial covenants at various times calculated monthly, quarterly or annually.  Failure to comply with the protective loan covenants or maintain the required financial ratios may cause acceleration of the outstanding principal balances on the loans and/or the imposition of fees, charges or penalties.  Any acceleration of the debt financing or imposition of the significant fees, charges or penalties may restrict or limit the access to the capital resources necessary to continue plant operations. As of June 30, 2010, the Company was in compliance with all covenants.  The Company made  a $5,000,000 free cash flow payment on the term loan on April 22, 2010.

 

Upon an occurrence of an event of default or an event which will lead to the default, Home Federal may upon notice terminate its commitment to loan funds and declare the entire unpaid principal balance of the loans, plus accrued interest, immediately due and payable.  Events of default include, but are not limited to, the failure to make payments when due, insolvency, any material adverse change in the financial condition or the breach of any of the covenants, representations or warranties the Company has given in connection with the transaction.

 

4.              RELATED PARTY TRANSACTIONS

 

The Company purchased corn and materials from members of its Board of Directors who own or manage elevators or are local producers of corn.  Purchases during the three and six months ended June 30, 2010, totaled approximately $0 and $6,308,000, respectively, and during the three and six months ended June 30, 2009 totaled approximately $4,097,000 and $4,510,000, respectively.  We did not have any corn purchases from related parties during the three month period ended June 30, 2010 because an elevator which was previously a related party, no longer qualifies as a related party.  We continue to purchase corn from this elevator.

 

On December 15, 2008, the Company entered into an agreement with Golden Grain Energy, LLC, a member of the Company, for management services.  Pursuant to the Agreement, Homeland Energy and Golden Grain have agreed to share management services in an effort to reduce the costs of administrative overhead. Homeland Energy and Golden Grain have agreed to split the compensation costs associated with each of the employees covered by the Agreement. For the three and six months ending June 30, 2010, the Company incurred net costs of approximately $76,000 and $183,000 related to this agreement.  The cost for the same period of 2009 related to this agreement were approximately  $103,000 and $225,000.

 

5.              COMMITMENTS, CONTINGENCIES AND AGREEMENTS

 

Ethanol,  Distiller’s grain, marketing agreements and major customers

The Company has entered into a marketing agreement to sell all ethanol produced at the plant to an unrelated party at a mutually agreed on price, less commission and transportation charges.  As of June 30, 2010, the Company has commitments to sell approximately 43,885,000 gallons at various fixed and basis price levels indexed against exchanges for delivery through March 2011. We had approximately 15,370,000 gallons at a fixed price level and approximately 28,515,000 at a basis price level.  Should the Company not be able to meet delivery on these gallons in the future the Company will be responsible for purchasing gallons in the open market.  The Company has not incurred any losses due to non-delivery of product and anticipates that all contracts will be sufficient to cover costs in the future.

 

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Table of Contents

 

HOMELAND ENERGY SOLUTIONS, LLC

Notes to Condensed Unaudited Financial Statements

 

June 30, 2010

 

The Company has entered into a marketing agreement to sell all distiller grains produced at the plant to an unrelated party at a mutually agreed on price, less commission and transportation charges.  The agreement was renewed for another one year term on April 1, 2010.  The agreement calls for automatic renewal for successive one-year terms unless 120-day prior written notice is given before the current term expires. As of June 30, 2010, the Company had approximately 33,000 tons of distiller grains commitments for delivery through December 2010 at various fixed prices. Should the Company not be able to meet delivery on these tons in the future, the Company will be responsible for fulfilling the commitment  in the open market.  The Company has not incurred any losses due to non-delivery of product.

 

Approximate sales and marketing fees related to the agreements in place for the three and six month period ending June 30, 2010 and 2009 are as follows below.

 

 

 

 

Three Months
ended

 

Six Months

 

Three Months
ended

 

Six Months

 

 

 

June 30, 2010

 

ended

 

June 30, 2009

 

Ended

 

 

 

 

 

 

 

 

 

 

 

Sales ethanol

 

$

46,648,000

 

$

95,107,000

 

$

32,814,000

 

$

32,814,000

 

Sales distiller grains

 

8,883,000

 

17,343,000

 

6,993,000

 

6,993,000

 

 

 

 

 

 

 

 

 

 

 

Marketing fees ethanol

 

397,000

 

767,000

 

261,000

 

261,000

 

Marketing fees distiller grains

 

164,000

 

281,000

 

119,000

 

119,000

 

 

 

 

As of June 30,
2010

 

As of June
30, 2009

 

 

 

 

 

 

Amount due from ethanol marketer

 

$

2,687,000

 

$

4,143,000

 

 

 

 

 

 

Amount due from distiller marketer

 

1,285,000

 

1,321,000

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

At June 30, 2010, the Company had outstanding commitments for purchases of approximately 9,774,000 bushels of corn at various prices through May 2011.

 

The Company has commitments for minimum purchases of various utilities such as natural gas and electricity over the next 10 years which are anticipated to approximate the following:

 

2010

 

$

1,975,000

 

2011

 

3,950,000

 

2012

 

3,950,000

 

2013

 

3,950,000

 

2014

 

3,908,000

 

Thereafter

 

16,015,000

 

Total anticipated commitments

 

$

33,750,000

 

 

6.              LEASE OBLIGATIONS

 

During fiscal year 2009 and 2010 the Company entered into leases for rail cars, rail moving equipment and loading equipment with original terms up to 5 years.  The Company is obligated to pay costs of insurance, taxes, repairs and maintenance pursuant to terms of the leases.  Rent expense incurred for the operating leases during the three and six  months ended June 30, 2010, was approximately $474,000 and $879,000 and for the same periods in 2009 was approximately $459,000 and $459,000.

 

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HOMELAND ENERGY SOLUTIONS, LLC

Notes to Condensed Unaudited Financial Statements

 

June 30, 2010

 

At June 30, 2010 the Company had the following approximate minimum rental commitments under non-cancelable operating leases.

 

2010

 

$

1,060,000

 

2011

 

2,012,000

 

2012

 

556,100

 

2013

 

117,500

 

2014

 

117,500
32,400

 

Total lease commitments

 

$

3,895,500

 

 

7.              DERIVATIVE INSTRUMENTS

 

The Company’s activities expose it to a variety of market risks, including the effects of changes in commodity prices.  These financial exposures are monitored and managed by the Company as an integral part of its overall risk-management program.  The Company’s risk management program focuses on the unpredictability of financial and commodities markets and seeks to reduce the potentially adverse effects that the volatility of these markets may have on its operating results.

 

To reduce price risk caused by market fluctuations, the Company generally follows a policy of using exchange traded futures and options contracts to reduce its net position of merchandisable agricultural commodity inventories and forward cash purchase and sales contracts and uses exchange traded futures and options contracts to reduce price risk.  Exchange-traded futures contracts are valued at market price.  Changes in market price of exchange traded futures and options contracts related to corn and natural gas are recorded in costs of goods sold and changes in market prices of contracts related to sale of ethanol, if applicable, are recorded in revenues.

 

The Company uses futures or options contracts to fix the purchase price of anticipated volumes of corn to be purchased and processed in a future month.  The Company’s plant will grind approximately 40 million bushels of corn per year.  During the previous period and over the next 12 months, the Company has hedged and anticipates hedging between 5% and 60% of its anticipated monthly grind.  At June 30, 2010, the Company has hedged portions of its anticipated monthly purchases for corn averaging approximately 23% of its anticipated monthly grind over the next twelve months.

 

Unrealized gains and losses on non-exchange traded forward contracts are deemed “normal purchases or sales” under authoritative accounting guidance and, as amended and, therefore, are not marked to market in the Company’s financial statements. The fair value of the Company’s open derivative positions are summarized in the following table as of June 30, 2010 and December 31, 2009.

 

 

 

Balance Sheet
Classification

 

Asset Fair
Value

 

Liability Fair
Value

 

Derivatives not designated as hedging instruments:

 

 

 

 

 

 

 

Commodity Contracts at 6/30/10

 

Derivative Instruments

 

$

31,863

 

$

 

 

 

 

 

 

 

 

 

Derivatives not designated as hedging instruments:

 

 

 

 

 

 

 

Commodity Contracts 12/31/09

 

Derivative Instruments

 

$

 

$

238,125

 

 

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HOMELAND ENERGY SOLUTIONS, LLC

Notes to Condensed Unaudited Financial Statements

 

June 30, 2010

 

The following table represents the amount of realized gains (losses) and changes in fair value recognized in earnings on commodity contracts for the three and six months ending June 30, 2010 and for the same periods ending June 30, 2009:

 

 

 

Income Statement
Classification

 

Realized
Gain (Loss)

 

Unrealized
Gain (Loss)

 

Total Gain
(Loss)

 

Derivatives not designated as hedging instruments:

 

 

 

 

 

 

 

 

 

Commodity Contracts for the three months ended 6/30/10

 

Cost of Goods Sold

 

$

1,443,357

 

$

31,863

 

$

1,475,220

 

 

 

 

 

 

 

 

 

 

 

·  Commodity Contracts for the six months ended 6/30/10

 

Cost of Goods Sold

 

$

2,933,986

 

31,863

 

2,965,849

 

 

 

 

 

 

 

 

 

 

 

Derivatives not designated as hedging instruments:

 

 

 

 

 

 

 

 

 

Commodity Contracts for the three months ended 6/30/09

 

 

 

 

 

 

 

 

 

 

Cost of Goods Sold

 

$

941,766

 

798,424

 

1,740,190

 

 

 

 

 

 

 

 

 

 

 

Commodity Contracts for the six months ended 6/30/09

 

Cost of Goods Sold

 

1,135,112

 

615,362

 

1,750,474

 

 

8.              FAIR VALUE MEASUREMENTS

 

Fair value is the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date.  In determining fair value, the Company uses various methods including market, income and cost approaches.  Based on these approaches, the Company often utilizes certain assumptions that market participants would use in pricing the asset or liability, including assumptions about risk and/or the risks inherent in the inputs to the valuation technique.  These inputs can be readily observable, market-corroborated, or generally unobservable inputs.  The Company utilizes valuation techniques that maximize the use of observable inputs and minimize the use of unobservable inputs.  Based on the observability of the inputs used in the valuation techniques, the Company is required to provide the following information according to the fair value hierarchy.  The fair value hierarchy ranks the quality and reliability of the information used to determine fair values.  Financial assets and liabilities carried at fair value will be classified and disclosed in one of the following three categories:

 

Level 1: Valuations for assets and liabilities traded in active markets from readily available pricing sources for market transactions involving identical assets or liabilities.

 

Level 2: Valuations for assets and liabilities traded in less active dealer or broker markets.  Valuations are obtained from third-party pricing services for identical or similar assets or liabilities.

 

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HOMELAND ENERGY SOLUTIONS, LLC

Notes to Condensed Unaudited Financial Statements

 

June 30, 2010

 

Level 3: Valuations incorporate certain assumptions and projections in determining the fair value assigned to such assets or liabilities.

 

A description of the valuation methodologies used for instruments measured at fair value, including the general classification of such instruments pursuant to the valuation hierarchy, is set forth below

 

Derivative financial instruments:  Commodity futures and exchange-traded commodity options contracts are reported at fair value utilizing Level 1 inputs.  For these contracts, the Company obtains fair value measurements from an independent pricing service.  The fair value measurements consider observable data that may include dealer quotes and live trading levels from the CBOT and NYMEX markets.

 

The following table summarizes financial assets and financial liabilities measured at fair value on a recurring basis as of June 30, 2010 and December 31, 2009, segregated by the level of the valuation inputs within the fair value hierarchy utilized to measure fair value:

 

 

 

Total

 

Level 1

 

Level 2

 

Level 3

 

 

 

 

 

 

 

 

 

 

 

Current Asset, derivative financial instruments at 6/30/10

 

$

31,863

 

$

31,863

 

 

 

 

 

 

 

 

 

 

 

 

 

Current Liability, derivative financial instruments at 12/31/09

 

238,125

 

238,125

 

 

 

 

Certain financial assets and financial liabilities are measured at fair value on a nonrecurring basis; that is, the instruments are not measured at fair value on an ongoing basis but are subject to fair value adjustments in certain circumstances, for example, when there is evidence of impairment.

 

The Company considers the carrying amount of significant classes of financial instruments on the balance sheets including cash, accounts receivable, due from broker, restricted cash, other assets, accounts payable, accrued liabilities and variable rate long-term debt to be reasonable estimates of fair value either due to their length of maturity or the existence of variable interest rates underlying such financial instruments that approximate prevailing market rates at June 30, 2010.

 

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

 

CAUTIONARY STATEMENTS REGARDING FORWARD-LOOKING STATEMENTS

 

This report contains forward-looking statements that involve future events, our future performance and our expected future operations and actions.  In some cases, you can identify forward-looking statements by the use of words such as “may,” “should,” “expect,” “plan,” “anticipate,” “believe,” “estimate,” “future,” “intend,” “could,” “will,” “hope,” “predict,” “target,” “potential,” or “continue” or the negative of these terms or other similar expressions.

 

These forward-looking statements are only our predictions and involve numerous assumptions, risks and uncertainties, including, but not limited to those listed below and those business risks and factors described elsewhere in this report and our other filings with the Securities and Exchange Commission.

 

·                  Our ability to satisfy the financial covenants contained in our credit agreements with our senior lender;

·                  Our ability to operate the ethanol plant profitably and maintain a positive spread between the price at which we sell our products and our raw materials costs;

·                  Our ability to generate free cash flow to invest in our business and service our debt;

·                  Volatility of corn, natural gas, ethanol, unleaded gasoline, distillers grains and other commodities prices and availability;

·                  Changes in general economic conditions or the occurrence of certain events causing an economic impact in the agriculture, oil or automobile industries;

·                  Elimination of the tariff on imported ethanol;

·                  Changes in interest rates or the lack of credit availability;

·                  Changes in our business strategy, capital improvements or development plans;

·                  The results of our hedging transactions and other risk management strategies;

·                  Our inelastic demand for and the availability of corn, as it is the only available feedstock for our plant;

·                  Changes in the environmental regulations or in our ability to comply with the environmental regulations that apply to our plant site and our operations;

·                  The effects of mergers, bankruptcies or consolidations in the ethanol industry;

·                  Changes in federal and/or state laws including the Renewable Fuels Standard and VEETC, or the elimination of any federal and/or state ethanol tax incentives;

·                  Overcapacity within the ethanol industry;

·                  Changes in plant production capacity or technical difficulties in operating the plant;

·                  Changes and advances in ethanol production technology that may make it more difficult for us to compete with other ethanol plants utilizing such technology;

·                  Our ability to retain key employees and maintain labor relations;

·                  The development of infrastructure related to the sale and distribution of ethanol; and

·                  Competition in the ethanol industry and from alternative fuel additives.

 

Our actual results or actions could and likely will differ materially from those anticipated in the forward-looking statements for many reasons, including but not limited to the reasons described in this report.  We are not under any duty to update the forward-looking statements contained in this report.  We cannot guarantee future results, levels of activity, performance or achievements.  We caution you not to put undue reliance on any forward-looking statements, which speak only as of the date of this report.  You should read this report and the documents that we reference in this report completely and with the understanding that our actual future results may be materially different from what we currently expect.  We qualify all of our forward-looking statements by these cautionary statements.

 

Available Information

 

Information about us is also available at our website at www.homelandenergysolutions.com, under “Investor Relations — SEC Filings,” which includes links to reports we have filed with the Securities and Exchange Commission. The contents of our website are not incorporated by reference in this Quarterly Report on Form 10-Q.

 

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Overview

 

Homeland Energy Solutions, LLC (referred to herein as “we,” “us,” the “Company,” “Homeland” or “Homeland Energy”) is an Iowa limited liability company.  Homeland was formed on December 7, 2005 for the purpose of pooling investors for the development, construction and operation of a 100 million gallon per year ethanol plant located near Lawler, Iowa.   We began producing ethanol and distillers grains at the plant in April 2009.  The ethanol plant is currently operating at a rate in excess of its nameplate capacity of 100 million gallons.

 

Prior to April 2009, we installed the infrastructure necessary to support plant operations and began operations.  We also obtained the permits required to construct and operate the plant. The total project cost was approximately $176 million, which included construction of our ethanol plant and start-up of operations.  We financed the construction and start-up of the ethanol plant with a combination of equity and debt.  We currently have 42 employees.

 

Our revenues are derived primarily from the sale of our ethanol and distillers grains.  We market and sell our products primarily in the continental United States through third party marketers.  We have an Ethanol Marketing Agreement with Green Plains Trade Group LLC (“GPTG”), which is the ethanol marketing and distribution subsidiary of Green Plains Renewable Energy, LLC (“GPRE”).  We have also entered into a Distillers Grains Marketing Agreement with CHS, Inc. (“CHS”), pursuant to which CHS purchases the distillers grains produced at our plant and sells them to its customers.

 

There have been a number of recent developments in legislation that impacts the ethanol industry.  One such development concerns the federal Renewable Fuels Standard (RFS).  The ethanol industry is benefited by the RFS which requires that a certain amount of renewable fuels must be used in the United States each year.  In February 2010, the EPA issued new regulations governing the RFS.  These new regulations have been called RFS2.  The most controversial part of RFS2 involves what is commonly referred to as the lifecycle analysis of greenhouse gas emissions.  Specifically, the EPA adopted rules to determine which renewable fuels provided sufficient reductions in greenhouse gases, compared to conventional gasoline, to qualify under the RFS program.  RFS2 establishes a tiered approach, where regular renewable fuels are required to accomplish a 20% greenhouse gas reduction compared to gasoline, advanced biofuels and biomass-based biodiesel must accomplish a 50% reduction in greenhouse gases, and cellulosic biofuels must accomplish a 60% reduction in greenhouse gases.  Any fuels that fail to meet this standard cannot be used by fuel blenders to satisfy their obligations under the RFS program.  The scientific method of calculating these greenhouse gas reductions has been a contentious issue.  Many in the ethanol industry were concerned that corn based ethanol would not meet the 20% greenhouse gas reduction requirement based on certain parts of the environmental impact model that many in the ethanol industry believed was scientifically suspect.  However, RFS2 as adopted by the EPA provides that corn-based ethanol from modern ethanol production processes does meet the definition of a renewable fuel under the RFS program.  Our ethanol plant was grandfathered into the RFS due to the fact that it was constructed prior to the effective date of the lifecycle greenhouse gas requirement and is not required to prove compliance with the lifecycle greenhouse gas reductions.  In addition, certain provisions of RFS2 as adopted by the EPA may disproportionately benefit ethanol produced from sugarcane.  This could make sugarcane based ethanol, which is primarily produced in Brazil, more competitive in the United States ethanol market.  If this were to occur, it could reduce demand for the corn based ethanol that we produce.

 

In addition to RFS2 which included greenhouse gas reduction requirements, in 2009, California passed a Low Carbon Fuels Standard (LCFS).  The California LCFS requires that renewable fuels used in California must accomplish certain reductions in greenhouse gases, measured using a lifecycle analysis similar to RFS2.  Management believes that this lifecycle analysis is based on unsound scientific principles that unfairly disadvantages corn based ethanol.  Management believes that these new regulations may preclude corn based ethanol from being used in California.  California represents a significant ethanol demand market.  If we are unable to supply ethanol to California, it could significantly reduce demand for the ethanol we produce.  Several lawsuits have been filed challenging the California LCFS.

 

In addition to the tax incentives, United States ethanol production is also benefited by a 54 cent per gallon tariff imposed on ethanol imported into the United States.  However, the 54 cent per gallon tariff is set to expire at

 

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Table of Contents

 

the end of the 2010 calendar year.  Elimination of the tariff that protects the United States ethanol industry could lead to the importation of ethanol produced in other countries, especially in areas of the United States that are easily accessible by international shipping ports.  Ethanol imported from other countries may be a less expensive alternative to domestically produced ethanol and may affect our ability to sell our ethanol profitably.

 

Ethanol production in the United States is benefited by various tax incentives.  The most significant of these tax incentives is the federal Volumetric Ethanol Excise Tax Credit (VEETC).  VEETC provides a volumetric ethanol excise tax credit of 4.5 cents per gallon of ethanol blended with gasoline at a rate of 10% (total credit of 45 cents per gallon of ethanol blended which is 4.5 divided by the 10% blend).  VEETC is scheduled to expire on December 31, 2010.  If this tax credit is not renewed, it likely would have a negative impact on the price of ethanol and demand for ethanol in the marketplace.

 

Demand for ethanol has been negatively affected by what is commonly referred to as the “blending wall.” The blending wall is an artificial cap on ethanol demand at approximately 13.5 billion gallons.  Currently, ethanol is blended with conventional gasoline for use in standard vehicles to create a blend which is 10% ethanol and 90% gasoline.  Estimates indicate that approximately 135 billion gallons of gasoline are sold in the United States each year.  Assuming that all gasoline in the United States is blended at a rate of 10% ethanol and 90% gasoline, the maximum demand for ethanol is 13.5 billion gallons per year.  Management believes that current ethanol supply is exceeding ethanol demand due to the effect of increased ethanol production and relatively stable ethanol demand due to the blending wall.  As the ethanol industry continues to approach the blending wall, the imbalance between ethanol supply and demand may increase.

 

In order to expand demand for ethanol, the ethanol industry has been pushing for an increase in the percentage of ethanol that can be used in standard (non-flex fuel) vehicles.  However, the automobile industry and some environmental groups have been lobbying against the use of higher ethanol blends in standard vehicles.  Currently, the EPA is considering allowing a blend of 15% ethanol and 85% gasoline (called E15) for use in standard vehicles.  However, the EPA has delayed making a decision on E15 until late in 2010.  The EPA has delayed a decision on E15 several times in the past and the EPA may continue to delay releasing a decision on the use of E15 in standard vehicles.  However, many in the ethanol industry believe that due to restrictions the EPA is expected to impose on the use of E15 in standard vehicles, such as only approving E15 for newer vehicles, the effect E15 may ultimately have on ethanol demand might be minimal.  Management believes that many gasoline retailers will refuse to provide E15 even if it is approved due to the fact that not all standard vehicles will be allowed to use E15 and the labeling requirements the EPA may impose likely will unfairly discourage consumers from using E15.  In addition to E15, the ethanol industry is pushing the use of an intermediate blend of 12% ethanol and 88% gasoline called E12.  Management believes that E12 may be more beneficial to the ethanol industry than E15 because many believe that E12 could be approved for use in all standard vehicles.  Management believes this will make it easier for retailers to supply E12 compared to E15.

 

Our ethanol plant became operational in early April 2009.  Therefore, our results of operations for the six and three months ended June 30, 2009 only include operations for less than three months.  Accordingly, the information we provide regarding our results of operations should be considered in light of the fact that the ethanol plant only operated for a portion of the 2009 periods covered in this report.

 

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Table of Contents

 

Results of Operations for the Three Months Ended June 30, 2010 and 2009

 

The following table shows the results of our operations and the percentage of revenues, cost of goods sold, operating expenses and other items to total revenues in our statement of operations for the three months ended June 30, 2010 and 2009.  Because we did not begin operating the plant until early April 2009, our operating data for the three months ended June 30, 2009 does not represent a full three month period.

 

 

 

Three Months Ended
June 30, 2010
(Unaudited)

 

Three Months Ended
June 30, 2009
(Unaudited)

 

Income Statement Data

 

Amount

 

%

 

Amount

 

%

 

Revenues

 

$

55,629,916

 

100.0

 

$

39,562,718

 

100.0

 

 

 

 

 

 

 

 

 

 

 

Cost of Goods Sold

 

52,519,070

 

94.4

 

38,133,578

 

96.4

 

 

 

 

 

 

 

 

 

 

 

Gross Profit

 

3,110,846

 

5.6

 

1,429,140

 

3.6

 

 

 

 

 

 

 

 

 

 

 

Selling, General and Administrative Expenses

 

564,278

 

1.0

 

150,199

 

0.4

 

 

 

 

 

 

 

 

 

 

 

Operating Income

 

2,546,568

 

4.6

 

1,278,941

 

3.2

 

 

 

 

 

 

 

 

 

 

 

Other Income (Expense)

 

(475,682

)

0.9

 

(232,607

)

0.6

 

 

 

 

 

 

 

 

 

 

 

Net Income

 

2,070,886

 

3.7

 

1,046,334

 

2.6

 

 

Revenues

 

We generated significantly more revenue for the second quarter of 2010 compared to the second quarter of 2009, primarily as a result of an increase in the amount of ethanol and distillers grains that we sold during the 2010 period.  The sale of ethanol and distillers grains is our only source of revenue.  For the second quarter of 2010, revenue from ethanol sales accounted for approximately 84% of our total revenue and distillers grains sales accounted for approximately 16% of our total revenue.  By comparison, for the second quarter of 2009, revenue from ethanol sales accounted for approximately 82% of our total revenue and distillers grains sales accounted for approximately 18% of our total revenue.  Our revenue is presented in our financial statements net of the shipping costs that are incurred in transporting our ethanol and distillers grains to the end customer.  These shipping charges are deducted by our ethanol and distillers grains marketers from the amounts realized on the sale of our ethanol and distillers grains.

 

During the second quarter of 2010, the average price we received for our ethanol was approximately 6% less than the average price we received during the second quarter of 2009.  Management attributes this decrease in the average price we received for our ethanol during the second quarter of 2010 compared to the same period of 2009 with lower corn prices and increased ethanol supply during the 2010 period which negatively impacted ethanol prices.  Ethanol prices tend to shift in relation to changes in the price of corn.  Further, as ethanol supply continues to come up against the blend wall, which artificially caps demand for ethanol, ethanol prices are negatively impacted.

 

Management anticipates that ethanol prices will be steady to lower for the rest of our 2010 fiscal year as the ethanol industry continues to experience increased ethanol supply with stable ethanol demand.  In order to maintain current ethanol prices, the ethanol industry must continue to expand ethanol demand.  Management anticipates that the implementation of higher blends of ethanol, such as E12, could increase demand for ethanol provided these higher blends are available to be used by all standard vehicles.  However, if E12 or E15 are only implemented for newer vehicles, such as has been suggested by the EPA, this could result in little or no increase in the use of ethanol which would not result in the necessary ethanol demand increases.  We experience some seasonality of demand for ethanol related to the summer driving season that management believes has a positive impact on ethanol prices.  Further, many ethanol plants schedule a shutdown during the early fall months for maintenance and cleaning.  This

 

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typically leads to decreased ethanol production during that time which may positively impact the price of ethanol during our third quarter.

 

The average price we received for both our dried distillers grains and wet distillers grains was lower for the second quarter of 2010 compared to the second quarter of 2009.  The average price we received per ton of dried distillers grains during the second quarter of 2010 was approximately 17% lower compared to the second quarter of 2009.  The average price we received per ton of wet distillers grains during the second quarter of 2010 was approximately 17% lower compared to the second quarter of 2009.  Management attributes this decrease in distillers grains prices with lower corn prices and increased distillers grains supplies.  As ethanol production increases, the amount of distillers grains that are produced also increases.  Management believes that domestic supply of distillers grains has exceeded domestic demand which has negatively impacted distillers grains prices.  However, distillers grains exports have recently increased which has somewhat offset the negative effects of the saturation of the domestic distillers grains markets.  The ethanol industry primarily exports distillers grains to Mexico, China and Canada.  Management anticipates that distillers grains prices will continue to follow corn prices.  However, any decrease in export demand for distillers grains may negatively impact the price we receive for our distillers grains.

 

The ethanol plant continues to produce ethanol and distillers grains at a rate that is in excess of our nameplate production capacity of 100 million gallons per year.  Management continues to fine tune the operation of the ethanol plant in an effort to increase the amount of ethanol and distillers grains that we can produce and to increase production efficiency.

 

Cost of Goods Sold

 

Our two primary costs of producing ethanol and distillers grains are corn costs and natural gas costs.   Our cost of goods sold was approximately 94.4% of our total revenues for the second quarter of 2010.  Our cost of goods sold was approximately 96.4% of our total revenues for the second quarter of 2009.  The average price we paid per bushel of corn during the second quarter of 2010 decreased by approximately 13% compared to the second quarter of 2009.  Management attributes this decrease to favorable weather that we have experienced during the 2010 growing season.  However, in June 2010, the USDA issued revisions to its projected number of acres that are planted with corn and reduced the amount of corn carryover.  This had a negative impact on corn prices and resulted in a greater weather premium in corn prices.  This weather premium typically dissipates during the end of August and early September when we get closer to harvest time provided we do not experience unfavorable weather conditions.  As a result of this increased uncertainty regarding corn supply, management believes that unfavorable weather conditions or increased global demand could result in significant increases in corn prices in a relatively short period of time.

 

The average price we paid per MMbtu of natural gas was approximately 22% higher for the second quarter of 2010 compared to the second quarter of 2009.  Management attributes this increase in natural gas prices with a more positive economic outlook.  However, natural gas supplies are comparable to last year so the increased natural gas prices are not necessarily related to actual increased natural gas demand.  Management anticipates that natural gas prices will be lower during the third quarter of 2010 as natural gas prices are typically lowest during August and September.  Following the lows in August and September, management anticipates increasing natural gas prices related to increased demand for heating needs.  We typically experience premium natural gas prices during the winter months.  Further, management anticipates that natural gas prices will continue to increase if global economic conditions continue to improve.

 

During the second quarter of 2010, we experienced an approximately $1.4 million realized gain and an unrealized gain of approximately $32,000 related to our corn and natural gas derivative instruments.  During the second quarter of 2009, we experienced an approximately $900,000 realized gain and an unrealized gain of approximately $800,000 related to our corn and natural gas derivative instruments.  For accounting purposes, we recognize the gains and losses that result from changes in the value of our derivative instruments in cost of goods sold as the changes occur.  Our plant is expected to grind approximately 40 million bushels of corn per year.  We anticipate entering into risk management positions with respect to approximately 5 to 60% of our annual corn needs.  As of June 30, 2010, we had risk management positions in place for approximately 23% of our corn needs for the next 12 months.  In addition, we anticipate entering into derivative instrument positions with respect to

 

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approximately 2 to 5% of our annual natural gas needs.  As of June 30, 2010, we had risk management positions in place for approximately 2% of our natural gas needs for the next 12 months.

 

Selling, General and Administrative Expenses

 

Our selling, general and administrative expenses were greater during the second quarter of 2010 compared to the second quarter of 2009.  Management attributes this increase with a reclassification of wages and benefits following our start-up in April 2009 that decreased the amount of selling, general and administrative expenses during the second quarter of 2009.

 

Other Income (Expense)

 

Our other expense was greater for the second quarter of 2010 compared to the second quarter of 2009.  We had grant income of $300,000 during the second quarter of 2009 which offset our interest expense during that period.  We had no grant income during the second quarter of 2010.

 

Results of Operations for the Six Months Ended June 30, 2010 and 2009

 

The following table shows the results of our operations and the percentage of revenues, cost of goods sold, operating expenses and other items to total revenues in our statement of operations for the six months ended June 30, 2010 and 2009.  The ethanol plant commenced operations in early April 2009.  Therefore, the results of our operations for the six months ended June 30, 2009 only represent approximately three months of operations compared to six months during the 2010 period.

 

 

 

Six Months Ended
June 30, 2010
(Unaudited)

 

Six Months Ended
June 30, 2009
(Unaudited)

 

Income Statement Data

 

Amount

 

%

 

Amount

 

%

 

Revenues

 

$

112,643,402

 

100.0

 

$

39,562,718

 

100.0

 

 

 

 

 

 

 

 

 

 

 

Cost of Goods Sold

 

102,356,914

 

90.9

 

38,133,578

 

96.4

 

 

 

 

 

 

 

 

 

 

 

Gross Profit

 

10,286,488

 

9.1

 

1,429,140

 

3.6

 

 

 

 

 

 

 

 

 

 

 

Selling, General and Administrative Expenses

 

1,134,895

 

1.0

 

1,366,736

 

3.5

 

 

 

 

 

 

 

 

 

 

 

Operating Income

 

9,151,593

 

8.1

 

62,404

 

0.2

 

 

 

 

 

 

 

 

 

 

 

Other Income (Expense)

 

(1,004,645

)

0.9

 

(155,050

)

0.4

 

 

 

 

 

 

 

 

 

 

 

Net Income (Loss)

 

8,146,948

 

7.2

 

(92,646

)

0.2

 

 

Revenues

 

Our revenue increased significantly for the six month period ended June 30, 2010 compared to the same period of 2009.  This increase in revenue was primarily the result of a significant increase in the amount of ethanol and distillers grains we sold during the 2010 period.  Our ethanol plant was only operational for approximately three of the six months during the 2009 period.  The average price we received per gallon of ethanol sold decreased by less than one percent during the six months ended June 30, 2010 compared to the same period of 2009.  However, the price we received per ton of distillers grains decreased during the six month period ended June 30, 2010 compared to the same period of 2009.  The average price we received per ton of dried distillers grains decreased by approximately 17% for the six month period ended June 30, 2010 compared to the same period of 2009.  The average price we received per ton of modified/wet distillers grains decreased by approximately 13% for the six month period ended June 30, 2010 compared to the same period of 2009.

 

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Cost of Goods Sold

 

Our cost of goods sold increased significantly for the six month period ended June 30, 2010 compared to the same six month period of 2009.  Due to the fact that we significantly increased our production of ethanol and distillers grains during the 2010 period, the cost of our raw materials increased significantly as well.  In addition to the increased quantity of corn and natural gas we purchased in order to increase our ethanol and distillers grains production, the average price we paid per bushel of corn decreased by approximately 11% for the six month period ended June 30, 2010 compared to the same period of 2009.  Further, our average price per MMbtu of natural gas during the 2010 period was approximately 43% higher compared to the 2009 period.  Due to the fact that our production of ethanol and distillers grains increased so significantly, a comparison of the relative costs of goods sold during the two periods is not indicative of our expectations for future periods.

 

Selling, General and Administrative Expenses

 

We experienced a slight decrease in our selling, general and administrative expenses during the six month period ended June 30, 2010 compared to the same period of 2009.  Generally, due to the fact that we were in operation the entire 2010 period, our selling, general and administrative expenses were higher during the 2010 period.  However, our legal expenses were significantly lower during the 2010 period and we had an asset impairment of approximately $481,000 which was included in our selling, general and administrative expenses during the 2009 period.

 

Other Income (Expense)

 

We experienced an increase in other expense for the six month period ended June 30, 2010 compared to the same period of 2009.  This increase was primarily the result of a significant increase in interest expense during the 2010 period along with the fact that we had other grant income of $300,000 during the 2009 period.  We experienced an increase in our interest expense during the 2010 period due to the fact that we were paying interest on our Home Federal loans during the entire six month period.  During the first six months of 2009, we were only required to pay interest on our Home Federal loans once the ethanol plant became operational in early April 2009.  Prior to that time, any interest that accrued on our Home Federal loans was capitalized.  Therefore, we included only approximately three months of interest during the 2009 period in our other expense.

 

Changes in Financial Condition for the Six Months Ended June 30, 2010

 

We experienced an increase in our current assets as of June 30, 2010 compared to December 31, 2009, primarily due to a significant increase in the amount of cash we had on hand.  We experienced an increase in the amount of cash we had on hand at June 30, 2010 compared to December 31, 2009 as a result of the continued profitable operation of the ethanol plant.  In addition, we experienced a significant decrease in the value of our accounts receivable at June 30, 2010 compared to December 31, 2009 due to timing issues related to when our finished products are shipped.  We ship a significant amount of our products by unit trains which can hold a significant amount of our finished products.  If these unit trains are shipped at the end of our fiscal quarter and we have not yet been paid by our marketers, we experience an increase in our accounts receivable.  We had approximately $870,000 due from our commodities broker at December 31, 2009 related to favorable derivative instrument positions we had in place at that time, and no amount due from our commodities broker at June 30, 2010.  We experienced a decrease in our prepaid expenses at June 30, 2010 compared to December 31, 2009 as a result of a natural gas deposit refund which we received in April 2010.

 

We experienced a decrease in the total value of our property and equipment at June 30, 2010 compared to December 31, 2009, primarily due to an increase in the accumulated depreciation of our buildings and equipment.  We had approximately $1.6 million in construction in progress at June 30, 2010 related to an efficiency improvement project that has been ongoing.

 

We experienced a decrease in our other assets at June 30, 2010 compared to December 31, 2009 as a result of our continuing amortization of our loan fees and utility rights, somewhat offset by interest income that accrued on our restricted cash account with Home Federal.

 

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We experienced a decrease in our current liabilities at June 30, 2010 compared to December 31, 2009, primarily due to a decrease in our accounts payable at June 30, 2010 compared to December 31, 2009.  This decrease in accounts payable was related to the fact that many of our corn suppliers seek to defer payments until after the end of their tax years on December 31.  This typically results in increased accounts payable at the end of our fiscal year.  This decrease in our accounts payable was somewhat offset by an increase in the current portion of our long-term debt at June 30, 2010 compared to December 31, 2009.  We commenced making principal payments on our long-term debt in February 2010.  As a result, the current portion of our long-term debt at December 31, 2010 only included approximately 11 months of principal payments compared to a full 12 months at June 30, 2010.  The total amount of our long-term debt was lower at June 30, 2010 compared to December 31, 2009 as a result of our continuing debt service payments and the $5 million free cash flow payment we made early in the second quarter of 2010.

 

Liquidity and Capital Resources

 

Our primary sources of liquidity are cash from our operations, our $20 million term revolving loan and our $6 million line of credit.  However, on June 30, 2010, our $6 million line of credit expired.  Our lender has indicated that we can renew this line of credit but management has decided not to renew this loan at this time.  These credit facilities are described in greater detail below under “Short-Term and Long-Term Debt Sources.”  As of June 30, 2010, we had $26 million available pursuant to the revolving loan and revolving line of credit, which was reduced to $20 million after June 30, 2010 when our $6 million line of credit expired.  In addition, we had approximately $9.7 million in cash and equivalents at June 30, 2010.  Based on financial forecasts performed by our management, we anticipate that we will have sufficient cash from our current credit facilities and cash from our operations to continue to operate the ethanol plant at capacity for the next 12 months.  We do not anticipate seeking additional equity or debt financing in the next 12 months.  However, should we experience unfavorable operating conditions in the future, we may have to secure additional debt or equity financing for working capital or other purposes.

 

The following table shows cash flows for the six months ended June 30, 2010 and 2009:

 

 

 

Six Months Ended June 30

 

 

 

2010

 

2009

 

Net cash provided by (used in) operating activities

 

$

18,592,738

 

$

(9,292,835

)

Net cash (used in) investing activities

 

$

(1,537,294

)

$

(25,819,970

)

Net cash provided by (used in) financing activities

 

$

(8,159,636

)

$

41,130,495

 

 

Operating Cash Flows.  We generated more cash from our operating activities during the six month period ended June 30, 2010 compared to the same period of 2009 because our plant was operational during the entire 2010 period.  Further, since we were just starting operations during the 2009 period, we used cash to build our inventories.

 

Investing Cash Flows.  We used less cash for investing activities during the six month period ended June 30, 2010 compared to the same period of 2009.  We used cash during the 2009 period for equipment purchases and construction in progress payments as we were completing the construction of our ethanol plant at that time.  During the 2010 period we used cash for construction in progress related to an ongoing efficiency improvement project.

 

Financing Cash Flows.  Our financing activities provided cash during the six month period ended June 30, 2009 due to approximately $41 million that we received from our Home Federal loans which we used to pay costs associated with the construction of our ethanol plant.  By comparison, during the six month period ended June 30, 2010, we used cash for our financing activities in making payments on our Home Federal term loan.  We did not receive any proceeds from our loans during the first six months of 2010.

 

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Short-Term and Long-Term Debt Sources

 

Master Loan Agreement with Home Federal Savings Bank

 

On November 30, 2007, we entered into a Master Loan Agreement with Home Federal Savings Bank (“Home Federal”) establishing a senior credit facility with Home Federal.  In return, we executed a mortgage in favor of Home Federal creating a senior lien on substantially all of our assets.  The Master Loan Agreement provides for a (i) $74 million term loan; (ii) $20 million term revolving loan; and (iii) $6 million revolving line of credit.

 

Term Loan

 

The original principal amount of the term loan was $74,000,000.  We made monthly payments of accrued interest on the term loan until February 1, 2010.  On February 1, 2010, we began making equal monthly principal payments in the amount of $616,667 plus accrued interest. All unpaid principal and accrued interest on the term loan will be due on July 1, 2014. We have the right to convert up to 50% of the term loan into a fixed rate loan with the consent of Home Federal. The fixed rate loan will bear interest at the five year London Interbank Offered Rate (LIBOR) swap rate that is in effect on the date of conversion plus 300 basis points, or another rate mutually agreed upon between us and Home Federal. If we elect this fixed rate option, the interest rate will not be subject to any adjustments otherwise provided for in the Master Loan Agreement. The remaining portion of the term loan will bear interest at a rate equal to the LIBOR plus 300 basis points.  As of June 30, 2010, the principal balance of the Home Federal term loan was approximately $60,916,667.  As of June 30, 2010, interest on the term loan accrued at an annual rate of 3.351%.

 

Term Revolving Loan

 

In addition to the term loan, we have a $20,000,000 term revolving loan which has a maturity date of July 1, 2014. Interest on the term revolving loan accrues at a rate equal to the LIBOR plus 300 basis points. We are required to make monthly payments of interest until the maturity date of the term revolving loan, on which date the unpaid principal amount of the term revolving loan becomes due.  As of June 30, 2010, we had no outstanding borrowing and $20,000,000 available to be drawn on the term revolving loan.

 

Revolving Line of Credit

 

Under the terms of the Master Loan Agreement, we agreed to the terms of a revolving line of credit. The revolving line of credit became available on July 1, 2009 and expired on June 30, 2010.  Management does not anticipate renewing this line of credit.  We had no amount outstanding on this line of credit on June 30, 2010.

 

If we fail to make a payment of principal or interest on any loan within 10 days of the due date, there will be a late charge equal to 5% of the amount of the payment.

 

Covenants

 

In connection with the Master Loan Agreement, we are required to comply with certain debt covenants and financial ratios.  As of June 30, 2010, we were in compliance with all of our debt covenants and financial ratios.  We are required to maintain a debt service reserve account of $10,000,000 for use by Home Federal for repayment of the loans.   Should Home Federal apply any of the funds in this account, we are required to replenish the account to $10,000,000.  We had in excess of $10,000,000 in our debt service reserve account as of June 30, 2010.  Once we achieve and maintain tangible net worth of 65%, based on audited financial statements, and we are in compliance with all other covenants, the debt service fund will be released to us and we will no longer be required to replenish the account.  However, should our tangible net worth fall below 65% at any time in the future, we would again be required to replenish the debt service fund.  Tangible net worth is calculated as the excess total assets, including the debt reserve account, (with certain exclusions, such as intangible assets) over total liabilities (except subordinated debt if applicable).  It is difficult to predict when and if we will achieve tangible net worth of 65%, however, we had tangible net worth of approximately 64% or approximately $115,072,000 as of June 30, 2010.

 

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In addition, we are subject to certain financial covenants at various times calculated monthly, quarterly or annually.  We were required to have working capital of at least $12,000,000 as of July 1, 2010 and annually thereafter.  Our tangible net worth requirement was $90,000,000 as of December 31, 2009, and increases by $5,000,000 annually until we are required to meet $105,000,000 by December 31, 2012, and annually thereafter.  Management anticipates that we will be in compliance with all of our debt covenants and financial ratios for the next 12 months.

 

Failure to comply with the loan covenants or maintain the required financial ratios may cause acceleration of the outstanding principal balances on the loans and/or the imposition of fees, charges or penalties.  Any acceleration of the debt financing or imposition of the significant fees, charges or penalties may restrict or limit our access to the capital resources necessary to continue plant operations.  Should we default on any of our obligations pursuant to the Home Federal loans, Home Federal may terminate its commitment to provide us funds and declare the entire unpaid principal balance of the loans, plus accrued interest, immediately due and payable.  Events of default include, the failure to make payments when due, our insolvency, any material adverse change in our financial condition or the breach of any of the covenants, representations or warranties we have in connection with the transaction.

 

We are required by the Master Loan Agreement to make an additional payment each year equal to 100% of our excess cash flow as that term is defined in the Master Loan Agreement.  This excess cash flow payment is capped at $5,000,000 each year.  Following the end of the first quarter of 2010, we made an excess cash flow payment of $5,000,000 to Home Federal.  As a result, we will make no further excess cash flow payments during our 2010 fiscal year.  We are only required to make the excess cash flow payment until our tangible net worth is equal to or greater than 65% of our total assets.

 

Grants and Government Programs

 

In addition to our equity and debt financing, we have applied for and received various grants.  In May 2006 we received a grant from the Iowa Corn Promotion Board in the amount of $25,000 for the preparation of our feasibility study and legal fees during our equity drive.

 

On December 19, 2007, the Iowa Department of Economic Development approved us for a package of benefits under the High Quality Jobs Program from the State of Iowa. Such tax benefits include a refund of sales, service and use taxes paid to contractors during the construction phase, an investment tax credit of up to $10,000,000 for qualified expenditures directly related to the new jobs created, and a property tax exemption for a portion of the value added by improvements we made to our property directly related to new jobs created by the plant (estimated at $10,350,000).  In order to receive these benefits, we are required to meet certain requirements by 2012, such as the creation of 40 full-time employee positions meeting certain minimum wage and benefit criteria.  These 40 positions must be maintained for at least two years following their creation. Currently, we have 42 employees and hope to maintain the minimum job requirement until 2012.   We also received a grant of $240,000 from the Iowa Department of Transportation under the RISE Program for the construction of a turning lane off of Iowa Highway 24 to the plant.

 

On September 16, 2009, we received notice that we had satisfied the conditions for disbursing the sales, service and use tax refund and the investment tax credit.  The Department of Economic Development agreement contains certain requirements that we must meet through 2012.  In the event that we fail to meet or maintain any one of the requirements of the High Quality Jobs Creation Program or Funding Agreement, we are subject to repayment of all or a portion of the incentives and assistance received based on specific provisions of the agreement.  The agreement provides that IDED may elect to have us repay a portion of the benefits received, on a pro rata basis, based on the number of jobs attained compared to the number of jobs pledged.  We have maintained all of the requirements to be met to date and have not incurred any liability for repayment of the incentives and assistance received.

 

We received preliminary approval for a loan guarantee of 60% of a potential $40,000,000 loan through Home Federal from the United States Department of Agriculture (“USDA”) under the Rural Energy Program based on some unique efficiencies at our plant.  However, we were required to meet certain conditions prior to the receipt of the loan guarantee which we have not yet been able to meet. We received an extension from the USDA of its

 

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commitment until November 2010.  However, if we do not meet those conditions by November 2010, we may not receive the guarantee.  Currently, the board has decided not to pursue this loan guarantee due to costs associated with the loan guarantee.

 

In June 2009, we were awarded a $300,000 working capital grant from the USDA pursuant to the Value-Added Producer Grant (“VAPG”) program.  Pursuant to the program, the USDA can provide up to 50% of the eligible project amount, which in our case was $625,000.  We are required to utilize the funds, as well as the $325,000 in matching funds, for corn, yeast, enzymes and processing chemical purchases.

 

Grants and Government Programs for Coal Gasification

 

We applied to the Iowa Power Fund for approximately $8,000,000 in funds to help finance the construction of a coal gasification energy center.  However, our application was rejected and we will not receive any funds from the Iowa Power Fund at this time.

 

We were awarded two unsecured loans from the Iowa Department of Economic Development.  The forgivable loan was subject to installation of coal gasification technology.  We repaid the interest free and forgivable loans in full on April 23, 2009 because we did not fulfill the coal gasification requirement of the IDED agreement.

 

Application of Critical Accounting Estimates and Significant Accounting Policies

 

Management uses estimates and assumptions in preparing our financial statements in accordance with generally accepted accounting principles.  These estimates and assumptions affect the reported amounts of assets and liabilities, the disclosure of contingent assets and liabilities, and the reported revenues and expenses.

 

We evaluate our contracts to determine whether the contracts are derivative instruments.  Certain contracts that literally meet the definition of a derivative may be exempted from derivative accounting as normal purchases or normal sales.  Normal purchases and normal sales are contracts that provide for the purchase or sale of something other than a financial instrument or derivative instrument that will be delivered in quantities expected to be used or sold over a reasonable period in the normal course of business.  Contracts that meet the requirements of normal purchases or sales are documented as normal and exempted from the accounting and reporting requirements of derivative accounting.

 

We enter into short-term cash, option and futures contracts as a means of securing purchases of corn, natural gas and sales of ethanol for the plant and managing exposure to changes in commodity and energy prices.  All of our derivatives are designated as non-hedge derivatives, with changes in fair value recognized in net income.  Although the contracts are economic hedges of specified risks, they are not designated as and accounted for as hedging instruments.

 

As part of our trading activity, we use futures and option contracts through regulated commodity exchanges to manage our risk related to pricing of inventories.  To reduce that risk, we generally take positions using cash and futures contracts and options.

 

Realized and unrealized gains and losses related to derivative contracts related to corn and natural gas are included as a component of cost of goods sold and derivative contracts related to ethanol are included as a component of revenues in the accompanying financial statements.  The fair values of contracts entered through commodity exchanges are presented on the accompanying balance sheet as derivative instruments.

 

Revenue from the sale of our products is recognized at the time title to the goods and all risks of ownership transfer to the customers.  This generally occurs upon shipment, loading of the goods or when the customer picks up the goods. Interest income is recognized as earned.  Shipping costs incurred in the sale of ethanol and distillers grains are not specifically identifiable and as a result, revenue from the sale of ethanol and distillers grains is recorded based on the net selling price reported to us from the marketer.

 

We consider the carrying amount of significant classes of financial instruments on the balance sheets including cash, accounts receivable, due from broker, restricted cash, other assets, accounts payable, accrued

 

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Table of Contents

 

liabilities and variable rate long-term debt to be reasonable estimates of fair value either due to their length of maturity or the existence of variable interest rates underlying such financial instruments that approximate prevailing market rates at June 30, 2010.

 

We review our property and equipment for impairment whenever events indicate that the carrying amount of the assets may not be recoverable.  If circumstances require a long-lived asset be tested for possible impairment, we first compare undiscounted cash flows expected to be generated by an asset to the carrying value of the asset. If the carrying value of the long-lived asset is not recoverable on an undiscounted cash flow basis, an impairment is recognized to the extent that the carrying value exceeds its fair value. Fair value is determined through various valuation techniques including discounted cash flow models, quoted market values and third-party independent appraisals, as considered necessary.

 

Off-Balance Sheet Arrangements

 

We do not have any off-balance sheet arrangements.

 

Item 3.  Quantitative and Qualitative Disclosures about Market Risk.

 

We are a smaller reporting company as defined by Rule 12b-2 of the Securities Exchange Act of 1934 and are not required to provide information under this item.

 

Item 4T.  Controls and Procedures.

 

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

 

Our management, including our President and Chief Executive Officer (the principal executive officer), Walter Wendland, along with our Chief Financial Officer, (the principal financial officer), Jeffrey Grober, have reviewed and evaluated the effectiveness of our disclosure controls and procedures as of June 30, 2010.  Based on this review and evaluation, these officers believe that our disclosure controls and procedures are effective in ensuring that material information related to us is recorded, processed, summarized and reported within the time periods required by the forms and rules of the Securities and Exchange Commission.

 

For the fiscal quarter ended June 30, 2010, there has been no change in our internal control over financial reporting 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

 

From time to time in the ordinary course of business, Homeland Energy Solutions, LLC may be named as a defendant in legal proceedings related to various issues, including without limitation, workers’ compensation claims, tort claims, or contractual disputes.  We are not currently involved in any material legal proceedings.

 

Item 1A.  Risk Factors.

 

We are a smaller reporting company as defined by Rule 12b-2 of the Securities Exchange Act of 1934 and are not required to provide information under this item.

 

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

 

None.

 

Item 3.  Defaults Upon Senior Securities

 

None.

 

Item 4.  (Removed and Reserved)

 

Item 5.  Other Information

 

None.

 

Item 6.  Exhibits

 

(a)           The following exhibits are filed as part of, or are incorporated by reference into, this report:

 

Exhibit
No.

 

Exhibit

 

Filed
Herewith

 

Incorporated by Reference

31.1

 

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

 

X

 

 

 

 

 

 

 

 

 

31.2

 

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

 

X

 

 

 

 

 

 

 

 

 

32.1

 

Certificate Pursuant to 18 U.S.C. Section 1350

 

X

 

 

 

 

 

 

 

 

 

32.2

 

Certificate Pursuant to 18 U.S.C. Section 1350

 

X

 

 

 

SIGNATURES

 

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

 

 

 

 

 

HOMELAND ENERGY SOLUTIONS, LLC

 

 

 

 

 

 

 

 

Date:

August 13, 2010

 

/s/ Walter W. Wendland

 

 

 

Walter W. Wendland

 

 

 

Chief Executive Officer and President (Principal Executive Officer)

 

 

 

 

 

 

 

 

Date:

August 13, 2010

 

/s/ Jeffrey S. Grober

 

 

 

Jeffrey S. Grober

 

 

 

Chief Financial Officer (Principal Financial and Accounting Officer)

 

26