10-K

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-K

x	Annual report pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934.
For the fiscal year ended		December 31, 2014
o	Transition report pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934.
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)	(Zip Code)
(563) 238-5555
(Registrant's telephone number, including area code)
Securities registered pursuant to Section 12(b) of the Act: None
Securities registered pursuant to Section 12(g) of the Act: Membership Units

Indicate by check mark if the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act.

o Yes x No

Indicate by check mark if the registrant is not required to file reports pursuant to Section 13 or Section 15(d) of the Act.

o Yes x No

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 Website, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files).

x Yes    o No

Indicate by check mark if disclosure of delinquent filers pursuant to Item 405 of Regulation S-K (§229.405 of this chapter) is not contained herein, and will not be contained, to the best of registrant's knowledge, in definitive proxy or information statements incorporated by reference in Part III of this Form 10-K or any amendment to this Form 10-K. x

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

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

As of June 30, 2014, the aggregate market value of the membership units held by non-affiliates (computed by reference to the most recent offering price of membership units) was $56,777,000.

As of February 27, 2015, there were 90,445 membership units outstanding. On June 13, 2013, the Company entered into an agreement with Steve Retterath, the Company's largest equity holder, to repurchase and retire all of the units owned by Mr. Retterath. The Company agreed to repurchase and retire 25,860 membership units owned by Mr. Retterath in exchange for $30 million. The Company believes that it has a binding agreement with Mr. Retterath. Mr. Retterath contends he is not bound by the agreement.  The Company's position is as of the closing date, Mr. Retterath is no longer the equitable owner of any membership units in the Company. As a result, the Company has recorded a $30 million short-term liability related to the amount the Company agreed to pay Mr. Retterath to repurchase his membership units and has correspondingly reduced members' equity on our balance sheet. The 90,445 membership units outstanding include the contested membership units the Company agreed to repurchase from Mr. Retterath.

DOCUMENTS INCORPORATED BY REFERENCE

The registrant has incorporated by reference into Part III of this Annual Report on Form 10-K portions of its definitive proxy statement to be filed with the Securities and Exchange Commission within 120 days after the close of the fiscal year covered by this Annual Report.

INDEX

	Page No.
Part I	3
Item 1. Business	3
Item 1A. Risk Factors	13
Item 2. Properties	17
Item 3. Legal Proceedings	18
Item 4. Mine Safety Disclosures	19
Part II	19
Item 5. Market for Registrant's Common Equity, Related Member Matters and Issuer Purchases of Equity Securities	19
Item 6. Selected Financial Data	21
Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations	22
Item 7A. Quantitative and Qualitative Disclosures About Market Risk	30
Item 8. Financial Statements and Supplementary Data	32
Item 9. Changes in and Disagreements with Accountants on Accounting and Financial Disclosure	47
Item 9A. Controls and Procedures	47
Item 9B. Other Information	49
Part III	49
Item 10. Directors, Executive Officers and Corporate Governance	49
Item 11. Executive Compensation	49
Item 12. Security Ownership of Certain Beneficial Owners and Management and Related Member Matters	49
Item 13. Certain Relationships and Related Transactions, and Director Independence	49
Item 14. Principal Accounting Fees and Services	49
Part IV	50
Item 15. Exhibits, Financial Statement Schedules	50
Signatures	53

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PART I

CAUTIONARY STATEMENTS REGARDING FORWARD-LOOKING STATEMENTS

This annual report contains historical information, as well as forward-looking statements that involve known and unknown risks and relate to future events, our future financial performance, or our expected future operations and actions. In some cases, you can identify forward-looking statements by terminology such as "may," "will," "should," "expect," "plan," "anticipate," "believe," "estimate," "future," "intend," "could," "hope," "predict," "target," "potential," or "continue" or the negative of these terms or other similar expressions. These forward-looking statements are only our predictions based on current information and involve numerous assumptions, risks and uncertainties. Our actual results or actions may differ materially from these forward-looking statements for many reasons, including the reasons described in this report. While it is impossible to identify all such factors, factors that could cause actual results to differ materially from those estimated by us include:

• Changes in the availability and price volatility of corn and natural gas;

• Reductions in the ethanol use requirement in the Federal Renewable Fuels Standard;

• Any delays in shipping our products by rail and corresponding decreases in our sales as a result of these shipping delays;

• Decreases in the market price of ethanol, distiller grains and corn oil;

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

• Our ability to continue to satisfy the financial covenants contained in our credit agreements with our lender;

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

• Our ability to generate sufficient liquidity to fund our operations, debt service requirements and capital expenditures;

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

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

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

• Changes in or elimination of federal and/or state laws having an impact on the ethanol industry;

• Overcapacity within the ethanol industry;

• Lack of transport, storage and blending infrastructure preventing our products from reaching high demand markets;

• 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 reliance on key management personnel; and

• Competition in the ethanol industry from alternative fuels.

The cautionary statements referred to in this section also should be considered in connection with any subsequent written or oral forward-looking statements that may be issued by us or any persons acting on our behalf. We undertake no duty to update these forward-looking statements, even though our situation may change in the future. Furthermore, we cannot guarantee future results, events, 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 and have filed as exhibits, 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 on 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 Annual Report on Form 10-K.

ITEM 1.BUSINESS.

Business Development

Homeland Energy Solutions, LLC (referred to herein as "we," "us," the "Company," "Homeland" or "Homeland Energy Solutions") is an Iowa limited liability company. We were formed on December 7, 2005 to build and operate a 100 million gallon per year ethanol plant located near Lawler, Iowa. The primary products produced at the plant are ethanol, distiller grains and corn oil. We commenced production on April 4, 2009. The ethanol plant is currently operating at a rate in excess of its nameplate production capacity of 100 million gallons of ethanol per year.

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On June 13, 2013, we entered into an agreement with Steve Retterath, our largest member, to repurchase and retire all of the units owned by Mr. Retterath. We agreed to close on this repurchase on or before August 1, 2013. We agreed to repurchase and retire the 25,860 membership units owned by Mr. Retterath in exchange for $30 million, to be paid in two equal installments payable at closing and on July 1, 2014. The transaction failed to close by the scheduled date due to objections by Mr. Retterath. The Company believes that it has a binding agreement with Mr. Retterath. On August 14, 2013, we filed a lawsuit against Mr. Retterath in Iowa to enforce the terms of the repurchase agreement. We are asking the Iowa court to require Mr. Retterath to complete the repurchase agreement pursuant to its terms. Mr. Retterath contends he is not bound by the agreement.  Our position is as of the closing date, Mr. Retterath is no longer the equitable owner of any membership units in the Company. As a result, we recorded a $30 million short-term liability related to the amount we agreed to pay Mr. Retterath to repurchase his membership units and we correspondingly reduced members' equity on our balance sheet. If we are ultimately unsuccessful in our lawsuit against Mr. Retterath, we will reevaluate the accounting considerations made during the period of time that the lawsuit is pending.

On the scheduled closing date for the repurchase agreement, Mr. Retterath sued the Company along with several directors, our former CEO, CFO, Plant Manager, a former director and our outside legal counsel in Florida state court. Details of both the Company's lawsuit against Mr. Retterath and Mr. Retterath's lawsuit are provided below in the section entitled "PART I - Item 3. Legal Proceedings."

On August 9, 2013, GS Cleantech Corporation ("GS Cleantech"), a subsidiary of Greenshift Corporation, filed a complaint in the United States District for the Northern District of Iowa against the Company. The Company is one of more than twenty ethanol manufacturers that were sued by GS Cleantech. The complaint alleges that Homeland's operation of a corn oil extraction process infringes patent rights claimed by GS Cleantech. GS Cleantech seeks royalties, damages and potentially triple damages associated with the alleged infringement, as well as attorney's fees. The complaint was transferred to the United States District Court for the Southern District of Indiana due to a finding that the action involves questions of fact common to several other lawsuits which were joined in a multi-district litigation ("MDL"). The MDL Court developed two tracks of defendants in this litigation. The first track includes defendants which were originally sued by GS Cleantech in 2010 and a second track of defendants sued in 2013 which includes the Company. On October 23, 2014, the MDL Court granted summary judgment in favor of the first track defendants and found that the GS Cleantech patents which the Company is alleged to have infringed are invalid. Further, in a January 16, 2015 decision, the MDL Court ruled in favor of a stipulated motion for partial summary judgment finding that all of the GS Cleantech patents in the suit were invalid and, therefore, not infringed.  GS Cleantech has said it will appeal this decision when the remaining claim in the suit has been decided. Regardless of when it may be appealed, the likelihood of GS Cleantech succeeding on appeal of the January 16, 2015 ruling is remote since it was based on several grounds for each allegedly infringed patent. If GS Cleantech successfully appeals the District Court’s findings of invalidity, damages awarded GS Cleantech may be $1 million or more.

The only remaining claim in the lawsuit alleges that GS Cleantech inequitably conducted itself before the United States Patent Office when obtaining the patents at issue. A trial in the District Court for the Southern District of Indiana on that single issue is scheduled. If the defendants, including the Company, succeed in proving inequitable conduct, the patents at issue will be invalidated such that no damages will be awarded to GS Cleantech for infringement and the MDL Court will be asked to determine whether GS Cleantech’s behavior makes this an "exceptional case". A finding that this is an exceptional case would allow the Court to award to Homeland an amount equal to the attorneys' fees the Company has expended to date for defense in this case. It is unknown whether GS Cleantech would appeal such a ruling.

On February 24, 2014, we executed amended loan agreements with our primary lender, Home Federal Savings Bank ("Home Federal"), pursuant to which Home Federal loaned us $15 million. The $15 million loan was structured as a term loan with a maturity date of March 1, 2019. The purpose of this term loan was to offset our liability associated with the Retterath repurchase agreement discussed above. The proceeds of this loan have been placed in a separate account to fund the payment due to Mr. Retterath pursuant to the repurchase agreement. Interest accrued on the term loan at an annual rate of 310 basis points in excess of the one month London Interbank Offered Rate (LIBOR), adjusted monthly. We agreed to make monthly principal and interest payments. During our second quarter of 2014, we repaid the entire principal balance of this loan.

During our 2014 fiscal year, legislative uncertainty existed in the ethanol industry which management believes impacted our financial performance. The ethanol industry is dependent on the ethanol use requirement in the Federal Renewable Fuels Standard (the "RFS"). The RFS requires that in each year an increasing amount of renewable fuels must be used in the United States. During our 2014 fiscal year, proposals were presented in Congress to reduce or eliminate the RFS. In addition, on November 15, 2013, the EPA announced a proposal to significantly reduce the RFS levels for 2014 from the statutory volume requirement of 18.15 billion gallons to 15.21 billion gallons and reduce the renewable volume obligation (RVO) that can be satisfied by corn based ethanol from 14.4 billion gallons to 13 billion gallons. The EPA proposal was subject to a 60-day public comment period which expired on January 28, 2014 and pursuant to which the EPA received a significant number of comments. On November 21,

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2014, the EPA announced that it will not issue a final RVO for 2014 before the end of 2014. Instead, the EPA announced that in 2015 it will set RVOs for 2014 through 2016. If the EPA elects to reduce the renewable fuels use requirements in the RFS in any material manner, the market price and demand for ethanol will likely decrease which will negatively impact our financial performance.

The ethanol industry continues to experience difficulty moving its finished products by rail. We have been impacted by these rail shipping delays. The shipping delays were the most severe during our first quarter of 2014 but these delays have occurred throughout 2014. The slower rail shipments have been due to a combination of factors including increased shipments of corn, coal and oil by rail, decreased shipment capacity by the railroads due to fewer railroad crews and bottlenecks on the railroads due to a lack of additional track where it is needed, and poor weather conditions which have slowed rail travel and loading times. Management anticipates that these slower rail shipments will continue for some period of time until the rail transportation capacity in the United States is expanded. While many ethanol producers are impacted by these rail shipment challenges, ethanol produced abroad may benefit due to higher domestic ethanol prices which could negatively impact demand for domestic supplies of ethanol.

On November 24, 2014, Walter Wendland ceased serving as our president and chief executive officer. Patrick Boyle was appointed by our board of directors to serve as our president and chief executive officer as of November 24, 2014. Mr. Boyle also serves as chairman of our board of directors.

Financial Information

Please refer to "Item 7 - Management's Discussion and Analysis of Financial Condition and Results of Operations" for information about our revenue, profit and loss measurements and total assets and liabilities and "Item 8 - Financial Statements and Supplementary Data" for our financial statements and supplementary data.

Principal Products

The principal products that we produce are ethanol, distiller grains and corn oil. The table below shows the approximate percentage of our total revenue which is attributed to each of our primary products for each of our last three fiscal years.

Product	Fiscal Year 2014		Fiscal Year 2013		Fiscal Year 2012
Ethanol	79	%	76	%	77	%
Distiller Grains	18	%	21	%	20	%
Corn Oil	3	%	3	%	3	%

Ethanol

Ethanol is ethyl alcohol, a fuel component made primarily from corn and various other grains. Ethanol is primarily used as: (i) an octane enhancer in fuels; (ii) an oxygenated fuel additive for the purpose of reducing ozone and carbon monoxide vehicle emissions; and (iii) a non-petroleum-based gasoline substitute. Ethanol produced in the United States is primarily used for blending with unleaded gasoline and other fuel products. Ethanol blended fuel is typically designated in the marketplace according to the percentage of the fuel that is ethanol, with the most common fuel blend being E10, which includes 10% ethanol. The United States Environmental Protection Agency ("EPA") has approved the use of gasoline blends that contain 15% ethanol, or E15, for use in all vehicles manufactured in model year 2001 and later. In addition, flexible fuel vehicles can use gasoline blends that contain up to 85% ethanol called E85.

Our ethanol plant uses corn as the feedstock in the ethanol production process. A corn-based ethanol plant is essentially a fermentation plant. Ground corn and water are mixed with enzymes and yeast to produce a substance called "beer," which contains approximately 15% alcohol, 11% solids and 74% water. The beer is boiled to separate the water, resulting in ethyl alcohol, which is then dehydrated to increase the alcohol content. This product is then mixed with a certified denaturant, such as gasoline, to make the product unfit for human consumption which allows it to be sold commercially.

Distiller Grains

The principal co-product of the ethanol production process is distiller grains, a high protein, high-energy animal feed supplement primarily marketed to the dairy and beef industry. We produce two forms of distiller grains: Modified/Wet Distiller Grains ("MWDG") and Distiller Dried Grains with Solubles ("DDGS"). MWDG is processed corn mash that has been dried to approximately 50% moisture. MWDG has a shelf life of approximately seven days and is often sold to markets near our ethanol

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plant. DDGS is processed corn mash that has been dried to approximately 10% moisture. It has a longer shelf life and may be sold and shipped to any market, regardless of its vicinity to our ethanol plant. We market nearly all of our distiller grains as DDGS.

Corn Oil

In October 2011, we commenced operating our corn oil extraction equipment. The corn oil extraction equipment we installed allows us to remove some of the corn oil contained in our distiller grains and sell the corn oil separately. The corn oil that we are capable of producing is not food grade corn-oil and it cannot be used for human consumption. The primary uses of the corn oil that we produce are for animal feed, industrial uses and biodiesel production.

Principal Product Markets

Ethanol

The primary market for our ethanol is the domestic fuel blending market. However, in recent years the United States has experienced increased ethanol exports. This increase in ethanol exports follows a conscious effort by the United States ethanol industry to expand ethanol exports along with lower ethanol prices which encourage exports. These ethanol export efforts are continuing and may lead to further increases in ethanol exports. The increase in ethanol exports along with lower ethanol imports contributed to improved operating margins in the United States for most of 2014 and has prevented excess ethanol supplies in the domestic market. Due to our location, we do not anticipate a significant amount of the ethanol we produce will be exported.

In 2011, the European Union launched anti-dumping and anti-subsidy investigations related to ethanol exports from the United States. In August 2012, the European Union concluded the anti-subsidy investigation and decided not to impose a tariff related to the anti-subsidy portion of the investigation due to the fact that the VEETC blenders credit had expired. However, the European Union decided to impose a tariff on ethanol imported from the United States based on the anti-dumping portion of the investigation. While this tariff has negatively impacted ethanol exports to the European Union, other countries have increased their ethanol imports. Further, some ethanol exports to the European Union have continued despite the tariff due to the relatively lower price of ethanol produced in the United States in 2014.

Ethanol is generally blended with gasoline before it is sold to the end consumer. Therefore, the primary purchasers of ethanol are fuel blending companies who mix the ethanol we produce with gasoline. As discussed below in the section entitled "Distribution of Principal Products," we have a third party marketer that sells all of our ethanol. Our ethanol marketer makes substantially all decisions regarding where our ethanol is sold.

Distiller Grains

Distiller grains are primarily used as animal feed. Distiller grains are typically fed to animals instead of other traditional animal feeds such as corn and soybean meal. Distiller grains exports have increased in recent years as distiller grains have become a more accepted animal feed. The primary export markets for distiller grains are China, Mexico, Turkey and Canada along with many Pacific Rim countries. However, demand for distiller grains from China decreased during the second half of 2014 when China announced in June 2014 that it would stop issuing import permits for distiller grains from the United States due to the presence in some shipments of a genetically modified corn trait not approved for import. This announcement was followed in July 2014 by a new requirement by China of a certification by the United States government that distiller grains shipments to China are free of the genetically modified corn trait. Officials from the United States and China were unable to agree on testing procedures for distiller grains exported to China. Recently, China has lifted these requirements for distiller grains produced in the United States which has reopened the Chinese market to United States distiller grains. However, China could reimpose this restriction at any time which makes the Chinese distiller grains market uncertain. We anticipate that the majority of our distillers grains will continue to be sold in the domestic market due to our plant's location, however, global distiller grains demand has an impact on domestic prices.

Corn Oil

The primary markets for corn oil are the industrial chemicals market, animal feeding market and the biodiesel production market. Domestic corn oil supplies have been increasing in recent years at a time when demand has been relatively stable which has resulted in decreasing corn oil prices. The market for corn oil is expected to continue to shift as changes in supply and demand of corn oil interact. Our corn oil is primarily marketed in the United States and we do not expect that significant exports of corn oil will occur in the near future.

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Distribution of Principal Products

We have hired third party marketers who are responsible for the distribution of all of the products we produce. Below is a description of the arrangements we have with our ethanol, distiller grains and corn oil marketers.

Ethanol Distribution

We have an ethanol marketing agreement with Renewable Products Marketing Group, Inc. ("RPMG"), a professional third party marketer, which is the sole marketer of our ethanol. RPMG also markets all of our corn oil. We are an equity owner of RPMG, LLC ("RPMG, LLC"), the parent company of RPMG, which allows us to realize favorable marketing fees and transparency in the sale of our ethanol and corn oil. Our ethanol marketing agreement provides we can sell our ethanol either through an index arrangement or at a fixed price agreed to between us and RPMG. The term of the ethanol marketing agreement is perpetual, until it is terminated. The primary reasons the ethanol marketing agreement would terminate are if we cease to be an owner of RPMG, LLC, if there is a breach of the ethanol marketing agreement which is not cured, or if we give advance notice to RPMG that we wish to terminate the ethanol marketing agreement. Notwithstanding our right to terminate the ethanol marketing agreement, we may be obligated to continue to market our ethanol through RPMG for a period of time after termination. Further, following termination, we would accept an assignment of certain railcar leases which RPMG has secured to service our ethanol sales. If our ethanol marketing agreement is terminated, it would trigger a redemption by RPMG, LLC of our ownership interest in RPMG, LLC.

Distiller Grains Distribution

We have a Distiller Grains Marketing Agreement with CHS, Inc. ("CHS"), pursuant to which CHS agreed to purchase all of the distiller grains produced at our plant. The initial term of the distiller grains marketing agreement was one year, beginning with the start-up of operations and production at the plant. After the initial one-year term, the agreement automatically renews for successive one year terms unless either party gives 90 days written notice of termination before the current term expires.

CHS agreed to pay us 98% of the actual sale price received by CHS from its customers for DDGS sold and 96% of the actual sale price received by CHS for MWDG sold, subject to certain minimum and maximum fees per ton. CHS deducts the customary freight costs incurred by CHS in delivering the distiller grains to its customers from our portion of the distiller grains sale price.

Corn Oil Distribution

In July 2011, we entered into a Corn Oil Marketing Agreement with RPMG. We have an exclusive marketing arrangement with RPMG where it will market all of the corn oil that we produce. We agreed to pay RPMG a commission based on each pound of corn oil that RPMG sells on our behalf. We also agreed to pay certain costs associated with RPMG marketing our corn oil. The initial term of the corn oil marketing agreement is for one year and the agreement automatically renews for additional one year terms unless written notice is given, either by us or RPMG, at least ninety days prior to the expiration of the current term of the agreement.

New Products and Services

We did not introduce any new products or services during our 2014 fiscal year.

Competition

We are in direct competition with numerous ethanol producers in the sale of our products and with respect to raw material purchases related to those products. Many of the ethanol producers with which we compete have greater resources than we do. While management believes we are a lower cost producer of ethanol, larger ethanol producers may be able to take advantage of economies of scale due to their larger size and increased bargaining power with both ethanol, distiller grains and corn oil customers as well as raw material suppliers. As of January 8, 2015, the Renewable Fuels Association estimates that there are 213 ethanol production facilities in the United States with capacity to produce approximately 15.1 billion gallons of ethanol per year. According to RFA estimates, approximately 3% of the ethanol production capacity in the United States was not operating as of January 8, 2015. The largest ethanol producers include Archer Daniels Midland, Flint Hills Resources, Green Plains Renewable Energy, POET, and Valero Renewable Fuels, each of which are capable of producing significantly more ethanol than we produce.

The following table identifies the largest ethanol producers in the United States along with their production capacities.

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U.S. FUEL ETHANOL PRODUCTION CAPACITY

BY TOP PRODUCERS

Producers of Approximately 700

million gallons per year (MMgy) or more

Company	Current Capacity (MMgy)	Under Construction/Expansions (MMgy)	Percent of Market
Archer Daniels Midland	1,762	—	12	%
POET Biorefining	1,626	—	11	%
Valero Renewable Fuels	1,240	—	8	%
Green Plains Renewable Energy	1,004	—	7	%
Flint Hills Resources	760	—	5	%

Updated: January 8, 2015

The products that we produce are commodities. Since our products are commodities, there are typically no significant differences between the products we produce and the products of our competitors that would allow us to distinguish our products in the market. As a result, competition in the ethanol industry is primarily based on price and consistent quality.

We have experienced increased competition from oil companies that have purchased ethanol production facilities. These oil companies are required to blend a certain amount of ethanol each year. Therefore, the oil companies may be able to operate their ethanol production facilities at times when it is unprofitable for us to operate our ethanol plant. Further, some ethanol producers own multiple ethanol plants which may allow them to compete more effectively by providing them flexibility to run certain production facilities while they have other facilities shut down. Finally, some ethanol producers who own ethanol plants in geographically diverse areas of the United States may spread the risk they encounter related to feedstock prices due to localized corn shortages or poor growing conditions.

We anticipate increased competition from renewable fuels that do not use corn as the feedstock. Many of the current ethanol production incentives are designed to encourage the production of renewable fuels using raw materials other than corn. One type of ethanol production feedstock that is being explored is cellulose. Cellulose is the main component of plant cell walls and is the most common organic compound on earth. Cellulose is found in wood chips, corn stalks, rice straw, amongst other common plants. Cellulosic ethanol is ethanol produced from cellulose. There are several commercial scale cellulosic ethanol production facilities either in production or in the construction phase which may be completed during 2015. If this technology can be profitably employed on a commercial scale, it could potentially lead to ethanol that is less expensive to produce than corn based ethanol, especially when corn prices are high. Cellulosic ethanol may also capture more government subsidies and assistance than corn based ethanol. This could decrease demand for our product or result in competitive disadvantages for our ethanol production process.

A number of automotive, industrial and power generation manufacturers are developing alternative clean power systems using fuel cells, plug-in hybrids, electric cars or clean burning gaseous fuels. Electric car technology has recently grown in popularity, especially in urban areas. While there are currently a limited number of vehicle recharging stations, making electric cars not feasible for all consumers, there has been increased focus on developing these recharging stations to make electric car technology more widely available in the future. Additional competition from these other sources of alternative energy, particularly in the automobile market, could reduce the demand for ethanol, which would negatively impact our profitability.

Competition among ethanol producers may continue to increase as gasoline demand decreases due to more fuel efficient vehicles being produced. If the concentration of ethanol used in most gasoline does not increase and gasoline demand is lower due to increased fuel efficiency by the vehicles operated in the United States, competition may increase among ethanol producers to supply the ethanol market.

Distiller Grains Competition

Our ethanol plant competes with other ethanol producers in the production and sales of distiller grains. Distiller grains are primarily used as an animal feed which replaces corn and soybean meal. As a result, we believe that distiller grains prices are positively impacted by increases in corn and soybean prices. In addition, in recent years the United States ethanol industry has increased exports of distiller grains which management believes has positively impacted demand and prices for distiller grains in the United States. In the event these distiller grains exports decrease, it could lead to an oversupply of distiller grains in the United

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States which could result in increased competition among ethanol producers for sales of distiller grains and could negatively impact distiller grains prices in the United States.

Corn Oil Competition

We compete with many ethanol producers for the sale of corn oil. Many ethanol producers have installed the equipment necessary to separate corn oil from the distiller grains they produce which has increased competition for corn oil sales and has resulted in lower market corn oil prices.

Sources and Availability of Raw Materials

Corn Supply

The major raw material required to produce ethanol, distiller grains and corn oil at our plant is corn. The ethanol plant is currently operating at a rate in excess of its nameplate capacity. We anticipate that we will require approximately 47 million bushels of corn per year to produce approximately 135 million gallons of ethanol per year. We buy as much corn as possible from local grain elevators and farmers. Our commodities manager is responsible for purchasing corn for our operations, scheduling corn deliveries and establishing hedging positions to protect the price we pay for corn.

During 2014, the United States harvested a record number of bushels of corn. Further, due to the large corn crop which was harvested in the fall of 2013, there was a significant carryover of corn from the prior havest. The large corn crop and higher carryover resulted in lower corn prices during our fourth fiscal quarter of 2014 and management anticipates that corn prices will remain lower during our 2015 fiscal year. However, if we experience unfavorable weather conditions, either throughout the United States or more locally in the corn area that serves the plant, we may experience higher corn prices and increased corn price volatility. Further, farmers may choose to plant less corn due to lower corn prices which could impact corn prices moving forward.

Commodities Account

In an attempt to minimize the effects of the volatility of corn costs on our profitability, we have two commodities trading accounts with ADM Investor Services, Inc. ("ADMIS"). In addition, we have a commodities manager who manages our corn procurement activities. ADMIS serves as our broker for the purchase and sale of commodity futures contracts for corn, and enters into transactions and exercises commodity options for our account in accordance with our instructions. We are required to maintain adequate margins in our accounts, and if we do not maintain adequate margins, ADMIS may close out any of our positions or transfer funds from our other accounts to cover the margin.

The effectiveness of our risk management strategy is dependent on the cost of corn and our ability to sell sufficient ethanol to use all of the corn for which we have futures contracts. Our risk management activities may not be successful in reducing the risk caused by price fluctuation, which may leave us vulnerable to high corn prices.

Utilities

We entered into an agreement with Northern Natural Gas in April 2008 for connection to its interstate pipeline and for transportation services for our natural gas supply. To access sufficient supplies of natural gas to operate the plant, a dedicated lateral pipeline from Northern Natural Gas's interstate pipeline has been constructed to service our plant. Construction of the natural gas lateral pipeline was completed prior to the commencement of our operations at the ethanol plant. We purchase our natural gas through various suppliers.

We entered into an Energy Management Services Agreement with U.S. Energy dated July 10, 2009. Pursuant to the agreement, U.S. Energy assists us with electric energy and natural gas management and procurement. U.S. Energy's responsibilities include administration of our gas supply contracts, nomination, scheduling and other logistical issues such as storage and transportation, negotiation and delivery. We work with U.S. Energy to provide estimated usage volumes on a monthly basis. In exchange for these management services, we pay a monthly service fee, as well as pre-approved expenses in connection with the services. The agreement for these services continues on a month to month basis.

On March 6, 2009, we entered into an Electrical Services Agreement with Hawkeye Tri-County Electric Cooperative (Hawkeye), to supply all of the electricity necessary to operate the ethanol plant. Pursuant to the agreement, Hawkeye has installed the electrical facilities necessary to deliver all of the electric power and energy required to operate our ethanol plant. The agreement with Hawkeye will remain in effect for ten years from the date we began processing ethanol at the plant (April 2009), and will terminate on the tenth anniversary of that date (April 2019). We may continue to receive the service following expiration of the

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ten-year term for a minimum of two years. Either party will then have the right to terminate the agreement upon six months' written notice.

Seasonality of Sales

We experience some seasonality of demand for our ethanol, distiller grains and corn oil. Since ethanol is predominantly blended with gasoline for use in automobiles, ethanol demand tends to shift in relation to gasoline demand. As a result, we experience some seasonality of demand for ethanol in the summer months related to increased driving and, as a result, increased gasoline demand. In addition, we experience some increased ethanol demand during holiday seasons related to increased gasoline demand. We also experience decreased distiller grains demand during the summer months due to natural depletion in the size of herds at cattle feed lots and when the animals are turned out to pasture or are slaughtered. Further, we expect some seasonality of demand for our corn oil since a major corn oil user is the biodiesel industry which typically reduces production during the winter months.

Working Capital

We primarily use our working capital for purchases of raw materials necessary to operate the ethanol plant, for payments on our credit facilities, for distributions to our members and for capital expenditures to maintain and upgrade the ethanol plant. Our primary sources of working capital are income from our operations as well as our revolving line of credit with our primary lender, Home Federal. For our 2015 fiscal year, we received a waiver from Home Federal of our capital expenditures covenant in order to complete a series of plant upgrade projects designed to make our plant more efficient and competitive. In addition, we anticipate continuing to conduct routine maintenance and repair activities at the ethanol plant. We anticipate using cash we generate from our operations and our revolving line of credit to finance these plant upgrade projects. Management believes that our current sources of working capital are sufficient to sustain our operations for our 2015 fiscal year and beyond.

Dependence on One or a Few Major Customers

As discussed previously, we have exclusive marketing agreements with RPMG for sales of our ethanol and corn oil and with CHS for sales of our distiller grains. As a result, we rely on RPMG and CHS for the sale and distribution of all of our products. Any loss of RPMG or CHS as the marketing agent for our products could have a significant negative impact on our revenues. While we anticipate that we could secure other ethanol, distiller grains and corn oil marketers if necessary, any loss of our marketers could significantly impact our ability to operate the ethanol plant profitably.

Patents, Trademarks, Licenses, Franchises and Concessions

We do not currently hold any patents, trademarks, franchises or concessions. We were granted a perpetual and royalty free license by ICM, Inc. ("ICM") to use certain ethanol production technology necessary to operate our ethanol plant. The cost of the license granted by ICM was included in the amount we paid to Fagen to design and build our ethanol plant.

Governmental Regulation and Federal Ethanol Supports

Federal Ethanol Supports

The ethanol industry is dependent on several economic incentives to produce ethanol, including federal tax incentives and ethanol use mandates. One significant federal ethanol support is the Federal Renewable Fuels Standard (the "RFS"). The RFS requires that in each year, a certain amount of renewable fuels must be used in the United States. The RFS is a national program that does not require that any renewable fuels be used in any particular area or state, allowing refiners to use renewable fuel blends in those areas where it is most cost-effective. The RFS statutory volume requirement increases incrementally each year until the United States is required to use 36 billion gallons of renewable fuels by 2022. Starting in 2009, the RFS required that a portion of the RFS must be met by certain "advanced" renewable fuels. These advanced renewable fuels include ethanol that is not made from corn, such as cellulosic ethanol and biomass based biodiesel. The use of these advanced renewable fuels increases each year as a percentage of the total renewable fuels required to be used in the United States.

The United States Environmental Protection Agency (the "EPA") has the authority to waive the RFS statutory volume requirement, in whole or in part, provided one of the following two conditions have been met: (1) there is inadequate domestic renewable fuel supply; or (2) implementation of the requirement would severely harm the economy or environment of a state, region or the United States. Annually, the EPA passes a rule that establishes the number of gallons of different types of renewable fuels that must be used in the United States which is called the renewable volume obligations.

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The RFS statutory volume requirement for 2014 is approximately 18.15 billion gallons, of which corn based ethanol can be used to satisfy approximately 14.4 billion gallons. The RFS statutory volume requirement for 2015 is approximately 20.5 billion gallons, of which corn based ethanol can be used to satisfy approximately 15 billion gallons. However, on November 15, 2013, the EPA announced a proposal to significantly reduce the RFS levels for 2014 to 15.21 billion gallons of which corn based ethanol could be used to satisfy only 13 billion gallons. This proposed rule would result in a lowering of the 2014 standard below the 2013 level of 13.8 billion gallons. The EPA also sought comment on several petitions it has received for partial waiver of the statutory volumes for 2014. The 60-day public comment period ended on January 28, 2014 and the rule was submitted by the EPA to the Office of Management and Budget for review on August 22, 2014. On November 21, 2014, the EPA announced that it would delay finalizing the rule on the 2014 RFS standards until after the end of 2014. The EPA indicated that it intends to take action on the 2014 standards in 2015 prior to or in conjunction with action on the 2015 standards. If the EPA's proposal becomes a final rule significantly reducing the volume requirements under the RFS or if the RFS were to be otherwise reduced or eliminated by the exercise of the EPA waiver authority or by Congress, the market price and demand for ethanol could decrease which will negatively impact our financial performance. Current ethanol production capacity exceeds the EPA's proposed 2014 standard which can be satisfied by corn based ethanol.

In February 2010, the EPA issued new regulations governing the RFS. These new regulations are 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. Many in the ethanol industry are concerned that certain provisions of RFS2 as adopted may disproportionately benefit ethanol produced from sugarcane which 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 ethanol that we produce.

Most ethanol that is used in the United States is sold in a blend called E10. E10 is a blend of 10% ethanol and 90% gasoline. E10 is approved for use in all standard vehicles. Estimates indicate that gasoline demand in the United States is approximately 134 billion gallons per 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 13.4 billion gallons per year. This is commonly referred to as the "blend wall," which represents a theoretical limit where more ethanol cannot be blended into the national gasoline pool. This is a theoretical limit because it is believed that it would not be possible to blend ethanol into every gallon of gasoline that is being used in the United States and it discounts the use of higher percentage blends such as E15 or E85. These higher percentage blends may lead to additional ethanol demand if they become more widely available and accepted by the market.

Many in the ethanol industry believe that it will be impossible to meet the RFS requirement in future years without an increase in the percentage of ethanol that can be blended with gasoline for use in standard (non-flex fuel) vehicles. The United States Environmental Protection Agency (the "EPA") has approved the use of E15, gasoline which is blended at a rate of 15% ethanol and 85% gasoline, in vehicles manufactured in the model year 2001 and later. However, there are still state hurdles that need to be addressed in some states before E15 will become more widely available. Many states still have regulatory issues that prevent the sale of E15. Sales of E15 may be limited because it is not approved for use in all vehicles, the EPA requires a label that management believes may discourage consumers from using E15, and retailers may choose not to sell E15 due to concerns regarding liability. In addition, different gasoline blendstocks may be required at certain times of the year in order to use E15 due to federal regulations related to fuel evaporative emissions which may limit E15 sales in these markets. As a result, the approval of E15 by the EPA has not had an immediate impact on ethanol demand in the United States.

State Ethanol Supports

In 2006, Iowa passed legislation promoting the use of renewable fuels in Iowa. One of the most significant provisions of the Iowa renewable fuels legislation is a renewable fuels standard encouraging 10% of the gasoline sold in Iowa to be renewable fuels by 2009 and increasing incrementally to 25% renewable fuels by 2019. This is expected to be achieved through the use of tax credits that are designed to encourage the further utilization of renewable fuels in Iowa. This legislation could increase local demand for ethanol and may increase the local price for ethanol. In 2011, the Iowa legislature increased the E85 tax credit to 18

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cents per gallon, created an E15 tax credit of 3 cents per gallon from 2011 until 2014, decreasing to 2.5 cents per gallon from 2015 until 2017 and waived the misfueling liability for retailers associated with E15. These changes were intended to encourage the use of higher level blends of ethanol in Iowa.

Effect of Governmental Regulation

The government's regulation of the environment changes constantly. We are subject to extensive air, water and other environmental regulations and we have been required to obtain a number of environmental permits to construct and operate the ethanol plant. It is possible that more stringent federal or state environmental rules or regulations could be adopted, which could increase our operating costs and expenses. It also is possible that federal or state environmental rules or regulations could be adopted that could have an adverse effect on the use of ethanol. Plant operations are governed by the Occupational Safety and Health Administration ("OSHA"). OSHA regulations may change such that the costs of operating the ethanol plant may increase. Any of these regulatory factors may result in higher costs or other adverse conditions effecting our operations, cash flows and financial performance.

In late 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 which is measured using a lifecycle analysis, similar to the RFS. On December 29, 2011, a federal district court in California ruled that the California LCFS was unconstitutional which halted implementation of the California LCFS. However, the California Air Resources Board ("CARB") appealed this court ruling and on September 18, 2013, the federal appellate court reversed the federal district court finding the LCFS constitutional and remanding the case back to federal district court to determine whether the LCFS imposes a burden on interstate commerce that is excessive in light of the local benefits. On June 30, 2014, the United States Supreme Court declined to hear the appeal of the federal appellate court ruling. In addition, a state court in California recently required that CARB take certain corrective actions regarding the approval of the LCFS regulations while allowing the LCFS regulations to remain in effect during this process. If federal and state challenges to the LCFS are ultimately unsuccessful, the LCFS could have a negative impact on demand for corn-based ethanol and result in decreased ethanol prices.

In 2012, the European Union concluded an anti-dumping investigation related to ethanol produced in the United States and exported to Europe. As a result of this investigation, the European Union has imposed a tariff on ethanol which is produced in the United States and exported to Europe. This tariff has resulted in significantly decreased exports of ethanol to Europe which has negatively impacted ethanol demand in the United States.

Costs and Effects of Compliance with Environmental Laws

We are subject to extensive air, water and other environmental regulations and we require a number of environmental permits to operate the plant. We have obtained all permits that are currently required for operation of the plant. In the fiscal year ended December 31, 2014, we incurred costs and expenses of approximately $159,000 complying with environmental laws, including the cost of obtaining permits. Although we have been successful in obtaining all of the permits currently required, any retroactive change in environmental regulations, either at the federal or state level, could require us to obtain additional or new permits or spend considerable resources in complying with such regulations. We anticipate incurring costs and expenses of approximately $150,000 for compliance with environmental laws for our fiscal year ended December 31, 2015.

Research and Development

We are continually working to develop new methods of operating the ethanol plant more efficiently. We continue to conduct research and development activities in order to realize these efficiency improvements.

Employees

As of December 31, 2014, we had 46 full-time employees. We do not anticipate a significant change in the number of full-time employees we have in the next 12 months.

Financial Information about Geographic Areas

All of our operations are domiciled in the United States. All of the products we sold to our customers for our fiscal years 2014, 2013, and 2012 were produced in the United States and all of our long-lived assets are domiciled in the United States. We have engaged third-party professional marketers that decide where our products are marketed and we have limited control over the marketing decisions made by our marketers. Our marketers may decide to sell our products in countries other than the United States. Currently, a significant amount of distiller grains are exported to Mexico, Canada and China and the United States ethanol

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industry exported significant amounts of ethanol to Canada, Philippines, Mexico and Brazil. However, we anticipate that our products will still primarily be marketed and sold in the United States.

ITEM 1A. RISK FACTORS.

You should carefully read and consider the risks and uncertainties below and the other information contained in this report. The risks and uncertainties described below are not the only ones we may face. The following risks, together with additional risks and uncertainties not currently known to us or that we currently deem immaterial could impair our financial condition and results of operation.

Risks Relating to Our Business

The spread between ethanol and corn prices can vary significantly which can negatively impact our financial condition. Our only source of revenue comes from sales of our ethanol, distiller grains and corn oil. The primary raw materials we use to produce our ethanol, distiller grains and corn oil are corn and natural gas. In order to operate the ethanol plant profitably, we must maintain a positive spread between the revenue we receive from sales of our products and our corn and natural gas costs. This spread between the market price of our products and our raw material costs has been volatile in the past, and management anticipates that this spread will likely continue to be volatile in the future. Due to a potential change in the ethanol use requirement in the RFS, demand for ethanol may be lower during our 2015 fiscal year which could result in tighter operating margins. In addition, lower gasoline prices have resulted in lower ethanol prices which has negatively impacted the spread between the price we receive for our ethanol and corn prices. If we were to experience a period of time where this spread is negative, and the negative margins continue for an extended period of time, it may prevent us from profitably operating the ethanol plant which could decrease the value of our units.

Decreasing gasoline prices may lower ethanol prices which could negatively impact our ability to operate profitably. In recent years, the price of ethanol has been less than the price of gasoline which increased demand for ethanol from fuel blenders. However, recently the price of gasoline has been decreasing significantly which has reduced the spread between the price of gasoline and the price of ethanol. This trend has negatively impacted ethanol prices. These lower ethanol prices have come at a time when corn prices are increasing which has decreased our profit margins. If this trend continues for a significant period of time, it could hurt our ability to profitably operate the ethanol plant which could decrease the value of our units.

Lack of rail transportation infrastructure and delayed rail shipments could negatively impact our financial performance. The ethanol industry has been experiencing difficulty transporting the ethanol which is produced by rail. This difficulty has impacted our operations. Ethanol is typically transported by rail. During the winter months of our 2014 fiscal year, we were required to reduce production due to shipping delays. Further, our ethanol inventory increased due to the difficulty we experienced shipping our ethanol which impacted our financial performance. The slower rail shipments were due to a combination of factors including increased shipments of corn, coal and oil by rail, decreased shipment capacity by the railroads due to fewer railroad crews, and poor weather conditions which have slowed rail travel and loading times. Management anticipates that these slower railcar shipments will continue for some period of time until the rail transportation capacity in the United States increases. These delays in shipping our products have resulted in decreased revenue and reduced the amount of ethanol we produced which has a negative impact on our financial performance. If these rail shipment challenges continue, they may negatively impact our ability to operate the ethanol plant profitably which could reduce the value of our units.

We may be forced to reduce production or cease production altogether if we are unable to secure the corn we require to operate the ethanol plant. Our ability to operate the ethanol plant requires us to purchase a sufficient amount of corn throughout the year in order to continuously operate the ethanol plant. If we are unable to secure the corn we require, either now or in the future, it could negatively impact our operations. We do not expect to encounter difficulty purchasing the corn we require due to the fact that the corn crop harvested in the fall of 2014 was the largest on record, however, shortages of corn could develop during the year or in future years. If we are unable to secure the corn we require to continue to operate the ethanol plant, we may have to reduce production or cease operating altogether which may negatively impact the value of our units.

We may violate the terms of our credit agreements and financial covenants which could result in our lender demanding immediate repayment of our loans. Our credit agreements with Home Federal require that we comply with various financial loan covenants. We are currently in compliance with all of our financial loan covenants. Current management projections indicate that we will be in compliance with our loan covenants for at least the next 12 months. However, unforeseen circumstances may develop which could result in us violating our loan covenants. If we violate the terms of our credit agreements, including our financial loan covenants, Home Federal could deem us to be in default of our loans and prevent us from drawing funds on our revolving line of credit and also require us to immediately repay the entire outstanding balance of our loans. If we do not have the

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funds available to repay the loans or we cannot find another source of financing, we may fail which could decrease or eliminate the value of our units.

Our marketers may fail to sell all of the ethanol, distiller grains and corn oil we produce which could negatively impact our profitability. We rely on our ethanol, distiller grains and corn oil marketers to sell all of our products. Currently we have an agreement with RPMG which markets all of our ethanol and corn oil and we have an agreement with CHS to market all of our distiller grains. Our only source of revenue is from the sale of our ethanol, distiller grains and corn oil. If our marketers are unable to sell all of the ethanol, distiller grains or corn oil we produce, or if they are unable to sell them at prices that allow us to operate profitability, the value of our units may be negatively impacted. Further, RPMG or CHS could fail. While we anticipate that we will be able to secure alternative marketers should RPMG or CHS cease marketing our products for any reason, we may not be able to do so without incurring additional costs or without a reduction in our revenue. Any loss of our ethanol, distiller grains or corn oil marketers may negatively impact our profitability and could decrease the value of our units.

We engage in hedging transactions which involve risks that can harm our business. We are exposed to market risk from changes in commodity prices. Exposure to commodity price risk results from our dependence on corn and natural gas in the ethanol production process. We seek to minimize the risks from fluctuations in the prices of corn and natural gas through the use of hedging instruments. These hedging instruments can be risky and can negatively impact our liquidity. In times when commodity prices are volatile, we may be required to use significant amounts of cash to make margin calls as a result of our hedging positions. The effectiveness of our hedging strategies is dependent on the cost of corn and natural gas and our ability to sell sufficient products to use all of the corn and natural gas for which we have futures contracts. Our hedging activities may not successfully reduce the risk caused by price fluctuations which may leave us vulnerable to high corn and natural gas prices. Alternatively, we may choose not to engage in hedging transactions in the future. As a result, our future results of operations and financial condition may also be adversely affected during periods in which corn and/or natural gas prices increase. These hedging transactions could impact our ability to profitably operate the ethanol plant and negatively impact our liquidity.

Our business is not diversified.  Our success depends almost entirely on our ability to profitably operate our ethanol plant. We do not have any other lines of business or other sources of revenue if we are unable to operate our ethanol plant and manufacture ethanol, distiller grains and corn oil.  If economic or political factors adversely affect the market for ethanol, distiller grains and corn oil, we have no other line of business to fall back on. Our business would also be significantly harmed if the ethanol plant could not operate at full capacity for any extended period of time which could reduce the value of our units.

We depend on our management and key employees, and the loss of these relationships could negatively impact our ability to operate profitably. We are highly dependent on our management team to operate our ethanol plant. Our management employees may decide to end their employment with us. If one or more of our management employees terminate their employment, we may not be able to replace these individuals. While we seek to compensate our management and key employees in a manner that will encourage them to continue their employment with us, they may choose to seek other employment. Any loss of these managers or key employees may prevent us from operating the ethanol plant profitably and could decrease the value of our units.

We may incur casualty losses that are not covered by insurance which could negatively impact the value of our units. We have purchased insurance which we believe adequately covers our losses from foreseeable risks. However, there are risks that we may encounter for which there is no insurance or for which insurance is not available on terms that are acceptable to us. If we experience a loss which materially impairs our ability to operate the ethanol plant which is not covered by insurance, the value of our units could be reduced or eliminated.

Our operations may be negatively impacted by natural disasters, severe weather conditions, and other unforeseen plant shutdowns which can negatively impact our operations. Our operations may be negatively impacted by events outside of our control such as natural disasters, severe weather, strikes, train derailments and other unforeseen events which may negatively impact our operations. If we experience any of these unforeseen circumstances which negatively impact our operations, it may affect our cash flow and negatively impact the value of our business.

Changes and advances in ethanol production technology could require us to incurcosts to update our plant or could otherwise hinder our ability tocompete in the ethanol industry or operate profitably.  Advances and changes in the technology of ethanol production are expected to occur.  Such advances and changes may make the ethanol production technology installed in our plant less desirable or obsolete.  These advances could also allow our competitors to produce ethanol at a lower cost than us.  If we are unable to adopt or incorporate technological advances, our ethanol production methods and processes could be less efficient than our competitors, which could cause our plant to become uncompetitive or completely obsolete.  If our competitors develop, obtain or license technology that is superior to ours or that makes our technology obsolete, we may be required to incur significant costs to enhance or acquire new technology so that our ethanol production remains competitive.  Alternatively, we may be required to seek third-party licenses, which could also result in significant expenditures.  These third-party licenses may not

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be available or, once obtained, they may not continue to be available on commercially reasonable terms.  These costs could negatively impact our financial performance by increasing our operating costs and reducing our net income.

Growth in the ethanol industry is dependent on growth in the fuel blending infrastructure to accommodate ethanol, which may be slow and could result in decreased ethanol demand. The ethanol industry depends on the fuel blending industry to blend the ethanol that is produced with gasoline so it may be sold to the end consumer. Substantial investments are required to expand this blending infrastructure and the fuel blending industry may choose not to expand the blending infrastructure to accommodate ethanol. Should the ability to blend ethanol not expand at the same rate as increases in ethanol supply, it may decrease the demand for ethanol which may lead to a decrease in the selling price of ethanol, which could impact our ability to operate profitably.

Risks Related to Ethanol Industry

Demand for ethanol may not increase past current levels unless higher percentage blends of ethanol are more widely used. Since ethanol is typically blended with gasoline, changes in gasoline demand affects demand for ethanol. In recent years, gasoline demand has been decreasing which has similarly impacted ethanol demand. While ethanol use has increased as more gallons of gasoline in the United States are blended with ethanol, this trend may not continue as ethanol is blended at a 10% rate in nearly all of the gasoline sold in the United States. In order to increase demand for ethanol past current levels, or to maintain current demand for ethanol if gasoline demand continues to decrease, the percentage of ethanol that is blended into gasoline must increase. While the EPA has approved the use of gasoline blends containing 15% ethanol (called E15) for use in vehicles produced in the model year 2001 and after, E15 has not become readily available in the marketplace. Demand for ethanol has been positively impacted by sales of E85 for use in flexible fuel vehicles, however, many in the ethanol industry believe that the best way to increase ethanol demand is through higher percentage blends of ethanol in standard vehicles. Opponents of ethanol, particularly the petroleum industry, have opposed the use of higher blends of ethanol in gasoline and are seeking to limit the use of ethanol. If ethanol demand decreases, particularly due to decreasing gasoline demand, it could negatively impact the price we receive for our ethanol which could negatively impact our ability to profitably operate the ethanol plant. Further, if domestic ethanol supplies increase, including through increased ethanol imports from Brazil, it could negatively impact demand for the ethanol we produce which could negatively impact our ability to profitably operate the ethanol plant.

Technology advances in the commercialization of cellulosic ethanol may decrease demand for corn-based ethanol which may negatively affect our profitability. The current trend in ethanol production research is to develop an efficient method of producing ethanol from cellulose-based biomass, such as agricultural waste, forest residue, municipal solid waste, and energy crops. This trend is driven by the fact that cellulose-based biomass is generally cheaper than corn, and producing ethanol from cellulose-based biomass would create opportunities to produce ethanol in areas of the country which are unable to grow corn. The Energy Independence and Security Act of 2007 and the 2008 Farm Bill offer strong incentives to develop commercial scale cellulosic ethanol. The RFS requires that 16 billion gallons per year of advanced bio-fuels, such as cellulosic ethanol, must be consumed in the United States by 2022. Additionally, state and federal grants have been awarded to several companies which are seeking to develop commercial scale cellulosic ethanol plants. This has encouraged innovation and has led to several companies which have completed construction or are in the process of building commercial scale cellulosic ethanol plants. If an efficient method of producing ethanol from cellulose-based biomass is developed, we may not be able to compete effectively. If we are unable to produce ethanol as cost-effectively as cellulose-based producers, our ability to generate revenue and our financial condition will be negatively impacted.

Changes and advances in ethanol production technology could require us to incur costs to update our plant or could otherwise hinder our ability to compete in the ethanol industry or operate profitably.  Advances and changes in the technology of ethanol production are expected to occur.  Such advances and changes may make the ethanol production technology installed in our plant less desirable or obsolete.  These advances could also allow our competitors to produce ethanol at a lower cost than we are able.  If we are unable to adopt or incorporate technological advances, our ethanol production methods and processes could be less efficient than our competitors, which could cause our plant to become uncompetitive or completely obsolete.  If our competitors develop, obtain or license technology that is superior to ours or that makes our technology obsolete, we may be required to incur significant costs to enhance or acquire new technology so that our ethanol production remains competitive.  Alternatively, we may be required to seek third-party licenses, which could also result in significant expenditures.  These third-party licenses may not be available or, once obtained, they may not continue to be available on commercially reasonable terms.  These costs could negatively impact our financial performance by increasing our operating costs and reducing our net income.

New plants under construction or decreases in ethanol demand may result in excess production capacity in our industry. The supply of domestically produced ethanol is at an all-time high. According to the Renewable Fuels Association, as of January 8, 2015, there are 213 ethanol plants in the United States with capacity to produce approximately 15.1 billion gallons of ethanol per year. In addition, there are 3 new ethanol plants under construction or expanding which together are estimated to

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increase ethanol production capacity by 100 million gallons per year. Excess ethanol production capacity may have an adverse impact on our results of operations, cash flows and general financial condition. According to the Renewable Fuels Association, approximately 3% of the ethanol production capacity in the United States was idled as of January 8, 2015. Further, ethanol demand may not increase past approximately 13.4 billion gallons of ethanol due to the blend wall unless higher percentage blends of ethanol are approved by the EPA for use in all standard (non-flex fuel) vehicles. While the United States is currently exporting some ethanol which has resulted in increased ethanol demand, these ethanol exports may not continue. If ethanol demand does not grow at the same pace as increases in supply, we expect the selling price of ethanol to decline. If excess capacity in the ethanol industry continues to occur, the market price of ethanol may decline to a level that is inadequate to generate sufficient cash flow to cover our costs, which could negatively affect our profitability.

We operate in an intensely competitive industry and compete with larger, better financed companies which could impact our ability to operate profitably.  There is significant competition among ethanol producers. There are numerous producer-owned and privately-owned ethanol plants planned and operating throughout the Midwest and elsewhere in the United States.  We also face competition from ethanol producers located outside of the United States. The largest ethanol producers include Archer Daniels Midland, Flint Hills Resources, Green Plains Renewable Energy, POET, and Valero Renewable Fuels, each which is capable of producing significantly more ethanol than we produce. Further, many believe that there will be consolidation occurring in the ethanol industry which will likely lead to a few companies which control a significant portion of the United States ethanol production market. We may not be able to compete with these larger producers. These larger ethanol producers may be able to affect the ethanol market in ways that are not beneficial to us which could negatively impact our financial performance and the value of our units.  

Competition from the advancement of alternative fuels may lessen demand for ethanol. Alternative fuels, gasoline oxygenates and ethanol production methods are continually under development. A number of automotive, industrial and power generation manufacturers are developing alternative clean power systems using fuel cells, plug-in hybrids, and electric cars or clean burning gaseous fuels. Like ethanol, these emerging technologies offer an option to address worldwide energy costs, the long-term availability of petroleum reserves and environmental concerns. If these alternative technologies continue to expand and gain broad acceptance and become readily available to consumers for motor vehicle use, we may not be able to compete effectively. This additional competition could reduce the demand for ethanol, resulting in lower ethanol prices that might adversely affect our results of operations and financial condition.

Consumer resistance to the use of ethanol based on the belief that ethanol is expensive, adds to air pollution, harms engines and/or takes more energy to produce than it contributes or based on perceived issues related to the use of corn as the feedstock to produce ethanol may affect demand for ethanol.  Certain individuals believe that the use of ethanol will have a negative impact on gasoline prices at the pump. Some also believe that ethanol adds to air pollution and harms car and truck engines. Still other consumers believe that the process of producing ethanol actually uses more fossil energy, such as oil and natural gas, than the amount of energy that is produced. Further, some consumers object to the fact that ethanol is produced using corn as the feedstock which these consumers perceive as negatively impacting food prices. These consumer beliefs could potentially be wide-spread and may be increasing as a result of recent efforts to increase the allowable percentage of ethanol that may be blended for use in vehicles. If consumers choose not to buy ethanol based on these beliefs, it would affect the demand for the ethanol we produce which could negatively affect our profitability and financial condition.

Risks Related to Regulation and Governmental Action

Government incentives for ethanol production may be eliminated in the future, which could hinder our ability to operate at a profit. The ethanol industry is assisted by various federal ethanol production and tax incentives, including the RFS set forth in the Energy Policy Act of 2005. The RFS helps support a market for ethanol that might disappear without this incentive.On November 15, 2013, the EPA announced a proposal to significantly reduce the RFS levels for 2014 to 15.21 billion gallons of which corn based ethanol could be used to satisfy only 13 billion gallons. This proposed rule would result in a lowering of the 2014 standard below the 2013 level of 13.8 billion gallons. The EPA also sought comment on several petitions it has received for partial waiver of the statutory volumes for 2014. The 60-day public comment period ended on January 28, 2014 and the rule was submitted by the EPA to the Office of Management and Budget for review on August 22, 2014. Furthermore, there have also been recent proposals in Congress to reduce or eliminate the RFS. On November 21, 2014, the EPA announced that it would delay finalizing the rule on the 2014 RFS standards until after the end of 2014. The EPA indicated that it intends to take action on the 2014 standards in 2015 prior to or in conjunction with action on the 2015 standards. If the EPA's proposal becomes a final rule significantly reducing the volume requirements under the RFS or if the RFS were to be otherwise reduced or eliminated by the exercise of the EPA waiver authority or by Congress, the market price and demand for ethanol could decrease which will negatively impact our financial performance.

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The Secondary Tariff on Imported Ethanol expired on December 31, 2011, and its absence could negatively impact our profitability. The secondary tariff on imported ethanol was allowed to expire on December 31, 2011. This secondary tariff on imported ethanol was a 54 cent per gallon tariff on ethanol produced in certain foreign countries. This made the United States a favorable market for foreign ethanol producers to export ethanol, especially in areas of the United States which are served by international shipping ports. Management believes that any increase in ethanol imports may negatively impact the demand for and price of ethanol produced in the United States which could negatively impact our financial condition and may reduce the value of our units.

The California Low Carbon Fuel Standard may decrease demand for corn based ethanol which could negatively impact our profitability. California passed a Low Carbon Fuels Standard ("LCFS") which requires that renewable fuels used in California must accomplish certain reductions in greenhouse gases which reductions are measured using a lifecycle analysis. Management believes that these regulations could preclude corn based ethanol produced in the Midwest from being used in California. California represents a significant ethanol demand market. If the ethanol industry is unable to supply corn based ethanol to California, it could significantly reduce demand for the ethanol we produce. This could result in a reduction of our revenues and negatively impact our ability to profitably operate the ethanol plant.

Changes in environmental regulations or violations of these regulations could be expensive and reduce our profitability.  We are subject to extensive air, water and other environmental laws and regulations.  In addition, some of these laws require our plant to operate under a number of environmental permits. These laws, regulations and permits can often require expensive pollution control equipment or operational changes to limit actual or potential impacts to the environment.  A violation of these laws and regulations or permit conditions can result in substantial fines, damages, criminal sanctions, permit revocations and/or plant shutdowns.  In the future, we may be subject to legal actions brought by environmental advocacy groups and other parties for actual or alleged violations of environmental laws or our permits.  Additionally, any changes in environmental laws and regulations, both at the federal and state level, could require us to spend considerable resources in order to comply with future environmental regulations. The expense of compliance could be significant enough to reduce our profitability and negatively affect our financial condition.

Carbon dioxide may be regulated in the future by the EPA as an air pollutant requiring us to obtain additional permits and install additional environmental mitigation equipment, which could adversely affect our financial performance. In 2007, the Supreme Court decided a case in which it ruled that carbon dioxide is an air pollutant under the Clean Air Act for motor vehicle emissions. In 2011 the EPA issued a tailoring rule that deferred greenhouse gas regulations for ethanol plants until July of 2014. However, in July of 2013 the D.C. Circuit issued an opinion vacating the EPA's deferral of those regulations for biogenic sources, including ethanol plants. On June 23, 2014 the U.S. Supreme Court affirmed in part and reversed in part the D.C. Circuit’s decision. For plants that already hold PSD permits the Court generally affirmed the EPA's ability to regulate greenhouse gas regulations. Our plant produces a significant amount of carbon dioxide. While there are currently no regulations restricting carbon dioxide emissions, if the EPA or the State of Iowa were to regulate carbon dioxide emissions by plants such as ours, we may have to apply for additional permits or we may be required to install carbon dioxide mitigation equipment or take other as yet unknown steps to comply with these potential regulations. Compliance with any future regulation of carbon dioxide, if it occurs, could be costly and may prevent us from operating the ethanol plant profitably which could decrease or eliminate the value of our units.

ITEM 2. PROPERTIES.

Our plant is located on an approximately 350 acre site in Chickasaw County, Iowa. The plant's address is 2779 Highway 24, Lawler, Iowa 52154. Construction of our plant was completed in April 2009. All of our operations are located at this site.

We selected our plant site because of its close proximity to rail service and access to natural gas supplies capable of meeting plant consumption needs. The plant is located on Iowa Highway 24, which runs east/west, and is about 10 miles east of Iowa Highway 63, which runs north/south, and about 40 miles north of Iowa Highway 20, which runs east/west. Our proximity to these highways provides us with easy access to Interstate 35 and Interstate 80. In addition, the plant is located on the Canadian Pacific railroad line which provides us access to many markets for our products.

All of our tangible and intangible property, real and personal, serves as the collateral for our debt financing with Home Federal Savings Bank, which is described below under "Item 7 - Management's Discussion and Analysis of Financial Condition and Results of Operations - Short-Term and Long-Term Debt Sources."

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ITEM 3. LEGAL PROCEEDINGS.

Retterath Florida Lawsuit

On August 1, 2013, Steve Retterath, the Company's largest investor and a former member of the Company's board of directors filed a lawsuit in the Florida Circuit Court located in Palm Beach County, Florida. The lawsuit was subsequently removed to federal court in Florida. In the lawsuit, Mr. Retterath sued the Company, Pat Boyle, Maurice Hyde, Christine Marchand, Mathew Driscoll, Leslie Hansen, and Chad Kuhlers, each members of the Company's board of directors, Walter Wendland, the Company's former Chief Executive Officer, David Finke, the Company's Chief Financial Officer and Kevin Howes, the Company's Plant Manager. Mr. Retterath also sued James Boeding, a former director and the Company's outside legal counsel, Joseph Leo and the BrownWinick Law Firm. Mr. Retterath is claiming that certain actions taken by the Company violated fiduciary duties owed to him as a member or fraudulently induced him to take certain actions. Mr. Retterath is also claiming violations of state and federal securities laws and violations of Florida's deceptive and unfair trade practices statutes. Mr. Retterath claims an unspecified damage in excess of $30 million in monetary damages. The Florida court ruled in favor of the Company's motion to transfer the case to Iowa. Each of the defendants filed motions to dismiss the lawsuit and Mr. Retterath filed a motion for partial summary judgment in the case. The Federal Court in Iowa ruled in favor of the defendants and dismissed the federal claims in this lawsuit. Further, the Federal Court declined jurisdiction to hear the other state law matters in the case and remanded the case to Florida state court. Mr. Retterath has filed a motion seeking to have the Federal Court in Iowa reconsider its decision on hearing the state court matters.

On August 21, 2014, Jason Retterath and Annie Retterath, the son and daughter-in-law of Steve Retterath, filed a motion to intervene in the lawsuit to protect their interests as members of the Company. The Company filed a motion to dismiss the intervenor petition. The Federal Court in Iowa declined to consider the Company's motion to dismiss the intervention and instead remanded the case back to Florida state court.

Retterath Iowa Lawsuit

On August 14, 2013, the Company filed a lawsuit against Steve Retterath in the Iowa state court located in Polk County, Iowa. The purpose of the lawsuit is to enforce the terms of the repurchase agreement we executed with Mr. Retterath on June 13, 2013. The Company is asking the Iowa state court to require Mr. Retterath to perform his obligations under the Retterath Repurchase Agreement pursuant to its terms. Mr. Retterath removed the case to federal court in the Federal District Court for the Southern District of Iowa in December 2013. The Company believed that this removal was improper and as a result the Company moved to remand the case back to the Iowa state court in Polk County which was granted. Mr. Retterath answered the lawsuit in August 2014, denying the validity of the repurchase agreement.

GS Cleantech Patent Litigation

On August 9, 2013, GS Cleantech Corporation ("GS Cleantech"), a subsidiary of Greenshift Corporation, filed a complaint in the United States District for the Northern District of Iowa against the Company. The Company is one of more than twenty ethanol manufacturers that were sued by GS Cleantech. The complaint alleges that the Company's operation of a corn oil extraction process infringes patent rights claimed by GS Cleantech. GS Cleantech seeks royalties, damages and potentially triple damages associated with the alleged infringement, as well as attorney's fees. The complaint was transferred to the United States District Court for the Southern District of Indiana due to a finding that the action involves questions of fact common to several other lawsuits which were joined in a multi-district litigation ("MDL"). The MDL Court developed two tracks of defendants in this litigation. The first track includes defendants which were originally sued by GS Cleantech in 2010 and a second track of defendants sued in 2013 which includes the Company. On October 23, 2014, the MDL Court granted summary judgment in favor of the first track defendants and found that the GS Cleantech patents which the Company is alleged to have infringed are invalid. Further, in a January 16, 2015 decision, the MDL ruled in favor of a stipulated motion for partial summary judgment finding that all of the GS Cleantech patents in the suit were invalid and, therefore, not infringed.  GS Cleantech has said it will appeal this decision when the remaining claim in the suit has been decided. Regardless of when it may be appealed, the likelihood of GS Cleantech succeeding on appeal of the January 16, 2015 ruling is remote since it was based on several grounds for each allegedly infringed patent. If GS Cleantech successfully appeals the District Court’s findings of invalidity, damages awarded GS Cleantech may be $1 million or more.

The only remaining claim in the lawsuit alleges that GS Cleantech inequitably conducted itself before the United States Patent Office when obtaining the patents at issue. A trial in the District Court for the Southern District of Indiana on that single issue is anticipated but has not yet been scheduled. If the defendants, including the Company, succeed in proving inequitable conduct, the patents at issue will be invalidated such that no damages will be awarded to GS Cleantech for infringement and the Court will be asked to determine whether GS Cleantech’s behavior makes this an "exceptional case". A finding that this is an

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exceptional case would allow the Court to award to the Company an amount equal to the attorneys' fees the Company has expended to date for defense in this case. It is unknown whether GS Cleantech would appeal such a ruling.

ITEM 4. MINE SAFETY DISCLOSURES

None.

PART II

ITEM 5. MARKET FOR REGISTRANT'S COMMON EQUITY, RELATED STOCKHOLDER MATTERS AND ISSUER PURCHASES OF EQUITY SECURITIES.

Outstanding Equity

As of February 27, 2015, we had 90,445 units outstanding and approximately 1,275 total members. On June 13, 2013, the Company entered into an agreement with Steve Retterath, the Company's largest equity holder, to repurchase and retire all of the units owned by Mr. Retterath. The Company agreed to repurchase and retire 25,860 membership units owned by Mr. Retterath in exchange for $30 million. The Company believes that it has a binding agreement with Mr. Retterath. Mr. Retterath contends he is not bound by the agreement.  The Company's position is as of the closing date, Mr. Retterath is no longer the equitable owner of any membership units in the Company. As a result, the Company has recorded a $30 million short-term liability related to the amount the Company agreed to pay Mr. Retterath to repurchase his membership units and has correspondingly reduced members' equity on our balance sheet. The 90,445 membership units outstanding include the contested membership units the Company agreed to repurchase from Mr. Retterath.

Unit Trading

There is no established public trading market for our units. However, on February 5, 2008, we established the Unit Trading Bulletin Board, which is a private online matching service, in order to facilitate trading among our members. The Unit Trading Bulletin Board consists of an electronic bulletin board on our website that provides a list of interested buyers and a list of interested sellers, along with their non-firm price quotes. The Unit Trading Bulletin Board does not automatically effect matches between potential sellers and buyers and it is the sole responsibility of sellers and buyers to contact each other to negotiate an agreement to transfer units. We do not become involved in any purchase or sale negotiations arising from our Unit Trading Bulletin Board and have no role in effecting transactions beyond approval, as required under our operating agreement, and the issuance of new certificates. We do not give advice regarding the merits or shortcomings of any particular transaction. We do not receive, transfer or hold funds or securities as an incident of operating the Unit Trading Bulletin Board. We do not receive any compensation for creating or maintaining the Unit Trading Bulletin Board. In advertising our Unit Trading Bulletin Board, we do not characterize Homeland Energy Solutions as being a broker or dealer or an exchange. We do not use the Unit Trading Bulletin Board to offer to buy or sell securities other than in compliance with the securities laws, including any applicable registration requirements.

There are detailed time lines that must be followed under the Unit Trading Bulletin Board rules and procedures with respect to offers and sales of membership units, with which all transactions must comply. In addition, all transactions must comply with our operating agreement, and are subject to approval by our board of directors.

The following table contains historical information by quarter for the past two years regarding the actual unit transactions that were completed by our unit-holders during the periods specified. Some of these transfers were made without consideration and as such no price information is included. We believe this most accurately represents the current trading value of our units. The information was compiled by reviewing the completed unit transfers that occurred on the Unit Trading Bulletin Board or through private transfers during the quarters indicated.

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Quarter	Low Price		High Price		Average Price		Number of Units Traded
First Quarter 2013	$	950	$	1,025	$	997	80
Second Quarter 2013	$	925	$	1,050	$	970	220
Third Quarter 2013	$	995	$	1,160	$	1,025	220
Fourth Quarter 2013	$	980	$	1,000	$	991	67
First Quarter 2014	$	1,040	$	1,100	$	1,070	50
Second Quarter 2014	$	1,075	$	1,400	$	1,285	125
Third Quarter 2014	$	1,400	$	1,450	$	1,419	65
Fourth Quarter 2014	$	1,600	$	1,800	$	1,680	50

The following tables contain the bid and asked prices that were posted on the Unit Trading Bulletin Board and includes some transactions that were not completed. We believe the table above more accurately describes the trading value of our units as the bid and asked prices below include some offers that never resulted in completed transactions. The information was compiled by reviewing postings that were made on the Unit Trading Bulletin Board.

Sellers' Quarter	Low Price		High Price		Average Price		Number of Units Listed
First Quarter 2013	$	950	$	1,200	$	1,075	205
Second Quarter 2013	$	995	$	1,500	$	1,248	175
Third Quarter 2013	$	1,100	$	1,100	$	1,100	25
Fourth Quarter 2013	$	—	$	—	$	—	—
First Quarter 2014	$	1,750	$	1,750	$	1,750	100
Second Quarter 2014	$	1,200	$	1,200	$	1,200	25
Third Quarter 2014	$	1,650	$	2,500	$	2,075	82
Fourth Quarter 2014	$	1,900	$	2,500	$	2,133	285

Buyers' Quarter	Low Price		High Price		Average Price		Number of Units Listed
First Quarter 2013	$	900	$	900	$	900	10
Second Quarter 2013	$	—	$	—	$	—	—
Third Quarter 2013	$	1,000	$	1,100	$	1,050	10
Fourth Quarter 2013	$	1,100	$	1,100	$	1,100	20
First Quarter 2014	$	1,150	$	1,150	$	1,150	50
Second Quarter 2014	$	1,000	$	1,450	$	1,196	295
Third Quarter 2014	$	1,425	$	1,700	$	1,593	347
Fourth Quarter 2014	$	—	$	—	$	—	—

As a limited liability company, we are required to restrict the transfers of our membership units in order to preserve our partnership tax status. Our membership units may not be traded on any established securities market or readily traded on a secondary market (or the substantial equivalent thereof). All transfers are subject to a determination that the transfer will not cause us to be deemed a publicly traded partnership.

Distributions

We paid distributions to our members in each of our last two fiscal years. Our board of directors paid a distribution of $131 per membership unit in December 2013. Our board of directors paid three distributions during our 2014 fiscal year for a total of $618 per membership unit with total distributions equaling $39,913,530. No distributions were paid to the contested membership units which are subject to the Retterath litigation. Our board of directors has discretion over the timing and amount of distributions to our unit holders subject to certain financial covenants required by our senior credit facility and restrictions under Iowa law. Our operating agreement requires the board of directors to endeavor to make cash distributions at such times and in such amounts as will permit our unit holders to satisfy their income tax liability in a timely fashion. Our expectations with respect

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to our ability to make future distributions are discussed in greater detail in "Item 7 - Management's Discussion And Analysis Of Financial Condition And Results Of Operations."

Performance Graph

The following graph shows a comparison of cumulative total member return since December 31, 2009, calculated on a dividend reinvested basis, for the Company, the NASDAQ Composite Index (the "NASDAQ Market Index") and an index of other companies that have the same SIC code as the Company (the "SIC Code Index"). The graph assumes $100 was invested in each of our units, the NASDAQ Market Index, and the SIC Code Index on December 31, 2009. Data points on the graph are quarterly. Note that historic unit price performance is not necessarily indicative of future unit price performance. The data for this performance graph was compiled for us by Zacks Investment Research, Inc.

Pursuant to the rules and regulations of the Securities and Exchange Commission, the performance graph and the information set forth therein shall not be deemed to be filed for purposes of Section 18 of the Securities Exchange Act of 1934, and shall not be deemed to be incorporated by reference in any filing under the Securities Act of 1933, as amended, or the Exchange Act, except as shall be expressly set forth by specific reference in such a filing.

ITEM 6. SELECTED FINANCIAL DATA

The following table presents selected financial and operating data as of the dates and for the periods indicated. The selected balance sheet financial data as of December 31, 2012, 2011 and 2010 and the selected income statement data and other financial data for the years ended December 31, 2011 and 2010 have been derived from our audited financial statements that are not included in this Form 10-K. The selected balance sheet financial data as of December 31, 2014 and 2013 and the selected income statement data and other financial data for each of the years in the three year period ended December 31, 2014 have been derived from the audited financial statements included elsewhere in this Form 10-K. You should read the following table in conjunction with "Item 7. Management Discussion and Analysis of Financial Condition and Results of Operations" and the financial statements and the accompanying notes included elsewhere in this Form 10-K. Among other things, those financial statements include more detailed information regarding the basis of presentation for the following financial data.

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	2014		2013		2012		2011		2010
Total Revenue	$	330,436,877	$	400,211,785	$	359,242,777	$	419,312,560	$	254,480,111
Net Income	68,615,951		28,233,908		494,765		36,353,768		11,030,809
Net Income Per Unit	1,062.41		359.48		5.47		401.94		120.63
Distributions Declared Per Unit	618.00		131.00		133.00		79.00		68.00
Total Assets	188,507,073		174,078,126		141,847,168		157,089,094		172,675,061
Long-term Liabilities	419,904		15,303,526		1,268,793		246,488		33,101,406
Members' Equity	147,849,311		119,146,890		129,373,617		140,692,427		112,483,814

ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

Results of Operations

Comparison of Fiscal Years Ended December 31, 2014 and 2013

	2014			2013
Income Statement Data	Amount		%	Amount		%
Revenue	$	330,436,877	100.0	$	400,211,785	100.0
Cost of goods sold	257,680,689		78.0	368,758,166		92.1
Gross profit	72,756,188		22.0	31,453,619		7.9
Selling, general and administrative expenses	4,716,195		1.4	3,380,466		0.8
Operating income	68,039,993		20.6	28,073,153		7.0
Total other income (expense)	575,958		0.2	160,755		—
Net income	$	68,615,951	20.8	$	28,233,908	7.1

Revenue

Our total revenue for our 2014 fiscal year was approximately 17% less than our total revenue for our 2013 fiscal year. Management attributes this decrease in revenue primarily with lower average ethanol prices and decreased ethanol sales during the 2014 period. Our revenue is presented in our financial statements net of the shipping costs that are incurred in transporting our products to the end customer. These shipping charges are deducted by our marketers from the amounts realized on the sale of our ethanol, distiller grains and corn oil.

For our 2014 fiscal year, our total ethanol revenue decreased by approximately 14% compared to our 2013 fiscal year due to lower average ethanol prices and decreased ethanol sales. The average price we received for our ethanol during our 2014 fiscal year was approximately 11% less than during our 2013 fiscal year. Management attributes this decrease in ethanol prices with lower corn and gasoline prices along with uncertainty regarding ethanol demand under the RFS during our 2014 fiscal year. Despite these lower prices for our products, during the first three quarters of our 2014 fiscal year, we experienced very favorable operating margins because the decrease in ethanol prices was less than the corresponding decrease in corn prices. However, these favorable operating margins were eroded during the fourth quarter of our 2014 fiscal year when oil and gasoline prices decreased sharply which pushed ethanol prices even lower. These lower ethanol prices and unfavorable operating margins have continued into our 2015 fiscal year and may last for some time if the price of gasoline remains low. Management believes demand for ethanol has been lower during our 2014 fiscal year as a result of uncertainty regarding the ethanol use requirement in the RFS. In November 2013, the EPA released a proposed rule which would significantly reduce the RFS for corn based ethanol in 2014. To date, this proposed rule has not been adopted by the EPA and the rule-making process is continuing. However, the possibility that the EPA may reduce the ethanol use requirement in the RFS has negatively impacted demand for ethanol as fuel blenders, who are required by the RFS to use ethanol, wait to see what requirements the EPA will put in place moving forward. In November 2014 the EPA indicated that the RFS requirements for 2014 will not be released until 2015. Further, the EPA has indicated that the RFS

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requirements for 2015 and 2016 may also be released in 2015. Until these rule-makings are complete, uncertainty will continue with respect to ethanol demand.

Management anticipates that ethanol prices will remain lower during our 2015 fiscal year due to anticipated low corn and gasoline prices along with uncertainty regarding the amount of domestic ethanol demand during our 2015 fiscal year. The lower ethanol prices may continue to result in unfavorable operating margins, particularly if corn prices increase during our 2015 fiscal year. However, management believes that ethanol exports may increase during our 2015 fiscal year if ethanol prices remain low which could provide additional ethanol demand. Further, if gasoline prices increase during our 2015 fiscal year, management believes it will positively impact ethanol prices. The recent decrease in gasoline prices resulted from lower oil prices. These lower oil prices are attributed to increased global oil supply. Many believe that the increase in the global oil supply was initiated by Saudi Arabia for political purposes. As a result, it is uncertain how long these lower oil and gasoline prices may last which has led to uncertainty regarding ethanol prices during our 2015 fiscal year. If gasoline prices are further reduced, it could result in negative operating margins which could hurt our financial performance. Management believes that our ethanol plant is a lower cost producer of ethanol which may allow us to survive these lower operating margins for longer than other ethanol producers.

In addition to the lower ethanol prices, we sold approximately 3% less gallons of ethanol during our 2014 fiscal year compared to the same period of 2013. Management attributes this decrease in total production of ethanol with rail logistics issues we experienced primarily during our first quarter of 2014 which reduced our total production and sales during that time. Rail shipping times normalized during our second through fourth quarters of 2014 which allowed us to operate the ethanol plant at full capacity. Management believes that the railroads do not have sufficient infrastructure and human capital to service existing and future demand which can result in slower rail shipping times, particularly during the winter months when poor weather can disrupt rail shipments. Management believes this lack of capacity by the railroads could continue for some time until sufficient investments are made by the railroads to meet current and future demand. Management anticipates that our ethanol production during our 2015 fiscal year will be comparable to or slightly higher than our 2014 fiscal year, provided we can maintain favorable operating margins which allow us to operate our ethanol plant at capacity during our 2015 fiscal year.

In addition to the lower ethanol revenue, our total distiller grains revenue was significantly lower during our 2014 fiscal year compared to the same period of 2013. Our total distiller grains revenue was approximately 28% less during our 2014 fiscal year compared to the same period of 2013 primarily due to lower distiller grains prices. We sold approximately 3% less tons of distiller grains during our 2014 fiscal year compared to the same period of 2013 due to decreased production during the 2014 period. The average prices we received for our distiller grains were lower during our 2014 fiscal year compared to the same period of 2013 due primarily to lower market corn prices and increased corn supplies. The average price we received per ton of modified/wet distiller grains sold decreased by approximately 40% during our 2014 fiscal year compared to the same period of 2013. The average price we received per ton of dried distiller grains sold decreased by approximately 25% during our 2014 fiscal year compared to the same period of 2013. Since distiller grains are primarily used as an animal feed substitute for corn and soybean meal, the price of distiller grains is impacted by these competing products. When soybean and corn supplies increase and the prices of these commodities are lower, it negatively impacts the price we receive for our distiller grains. Management anticipates continued lower corn and soybean prices which may result in lower distiller grains prices. However, if ethanol producers slow or cease production, it may increase demand for distiller grains since many animal feeders rely on a certain amount of distiller grains in their feed rations. It can be difficult to adjust these feed rations in the short term which can result in higher distiller grains prices when the market supply for distiller grains is lower.

We had less revenue from corn oil sales during our 2014 fiscal year compared to the same period of 2013, due to lower corn oil prices and lower total pounds of corn oil sold. The average price we received for our corn oil during our 2014 fiscal year was approximately 14% less than the average price we received during the same period of 2013. Management attributes this decrease in corn oil prices with a combination of increased corn oil production by the ethanol industry along with lower corn oil demand. Management also believes lower corn prices negatively impacted corn oil prices during our 2014 fiscal year. In addition, management believes corn oil demand was negatively impacted by the loss of the biodiesel blenders' credit during 2014 since the biodiesel industry is a major source of corn oil demand.

We produced approximately 17% less pounds of corn oil during our 2014 fiscal year compared to the same period of 2013. Management attributes this decrease in corn oil production with decreased production by the ethanol plant generally along with a decrease in the amount of corn oil contained in the corn we used during our 2014 fiscal year compared to the corn we used during our 2013 fiscal year. The corn we used during our 2013 fiscal year contained more corn oil and the corn oil was easier to separate compared to the corn we used during our 2014 fiscal year. This change in the corn we used resulted in lower corn oil extraction efficiency which negatively impacted our total corn oil production.

Management anticipates that corn oil prices will remain lower during our 2015 fiscal year due to uncertainty regarding biodiesel production since the tax credit which supported biodiesel production in the past was allowed to expire at the end of 2013

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and was not renewed prospectively for 2015. The biodiesel blenders' credit was renewed at the end of 2014 but only retroactively for biodiesel produced during 2014. Biodiesel production is a major source of corn oil demand and without strong demand from the biodiesel industry, corn oil prices may continue lower during our 2015 fiscal year. Further, management anticipates stronger corn oil production during our 2015 fiscal year as a result of the composition of the corn harvested in the fall of 2014 which seems to have more corn oil compared to the previous year.

Cost of Goods Sold

Our two primary costs of producing ethanol, distiller grains and corn oil are corn costs and natural gas costs. Our total cost of goods sold was approximately 30% less during our 2014 fiscal year compared to the same period of 2013 due to lower corn prices and consumption partially offset by higher natural gas prices.

The average price we paid per bushel of corn, without taking into account derivative instruments, was approximately 35% lower during our 2014 fiscal year compared to our 2013 fiscal year. Management attributes this decrease in the average price we paid per bushel of corn with lower market corn prices throughout our 2014 fiscal year compared to our 2013 fiscal year. Management attributes the decrease in market corn prices with a strong corn crop during the fall of 2013 along with a record corn crop harvested in the fall of 2014. Management anticipates that corn prices will remain lower during our 2015 fiscal year due to the large corn supply and uncertainty regarding corn demand because uncertainty regarding whether the EPA will reduce the RFS may result in lower demand for corn. Further, if the EPA does in fact reduce the RFS, it is possible that corn prices will decrease further. In addition to the lower corn prices, our cost of goods sold was lower during our 2014 fiscal year due to $4.5 million in combined realized and unrealized gains on our risk management positions which reduced our cost of goods sold. By comparison, we had combined realized and unrealized gains on our risk management positions which decreased our cost of goods sold by approximately $5.5 million during our 2013 fiscal year.

We purchased approximately 2% less bushels of corn during our 2014 fiscal year compared to our 2013 fiscal year. Management attributes this decrease in corn consumption with deceased production during the 2014 period. Management anticipates that our corn consumption will be comparable during our 2015 fiscal year to our 2014 fiscal year.

During our 2014 fiscal year, the average price we paid per MMBtu of natural gas was approximately 42% greater compared to our 2013 fiscal year. Management attributes this increase in natural gas prices to a longer and colder winter during our 2014 fiscal year which increased our natural gas transportation costs. Our natural gas costs normalized during the summer months of our 2014 fiscal year as natural gas stocks returned to more normal levels. However, management believes that these higher natural gas prices could return if we experience colder weather during our 2015 fiscal year which depletes natural gas supplies. We expect higher natural gas prices during winter months due to annual increases in natural gas transportation costs. We consumed approximately 2% less natural gas during our 2014 fiscal year compared to the same period of 2013 primarily due to decreased production at the ethanol plant. We expect our natural gas consumption to continue to track our total production.

Selling, General and Administrative Expenses

Our selling, general and administrative expenses were significantly higher during our 2014 fiscal year compared to our 2013 fiscal year due primarily to legal expenses we have incurred related to the various lawsuits in which we are involved.

Other Income (Expense)

We had more interest expense during our 2014 fiscal year compared to the same period of 2013 due to the term loan we secured to finance a portion of the Retterath repurchase. This loan was repaid during the second quarter of our 2014 fiscal year. We had more interest income during our 2014 fiscal year compared to the same period of 2013 due to having more cash on hand during the 2014 period. We had more other income during our 2014 fiscal year compared to the same period of 2013 primarily due to having more investment income from our investment in RPMG, our ethanol and corn oil marketer along with unrealized gains we had on trading securities we purchased with additional cash we had available during our 2014 fiscal year.

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Comparison of Fiscal Years Ended December 31, 2013 and 2012

	2013			2012
Income Statement Data	Amount		%	Amount		%
Revenue	$	400,211,785	100.0	$	359,242,777	100.0
Cost of goods sold	368,758,166		92.1	356,064,736		99.1
Gross profit	31,453,619		7.9	3,178,041		0.9
Selling, general and administrative expenses	3,380,466		0.8	2,758,898		0.8
Operating income	28,073,153		7.0	419,143		0.1
Total other income (expense)	160,755		—	75,622		—
Net income	$	28,233,908	7.1	$	494,765	0.1

Revenue

Our total revenue for our 2013 fiscal year was approximately 11% greater than our total revenue for our 2012 fiscal year. Management attributes this increase in revenue with increased production and prices for our ethanol and distiller grains during our 2013 fiscal year compared to our 2012 fiscal year.

For our 2013 fiscal year, our total ethanol revenue increased by approximately 11% compared to our 2012 fiscal year due to higher ethanol prices and increased ethanol production. This increase in prices and production was offset slightly by approximately $343,000 in realized and unrealized losses on ethanol hedging activities. The average price we received for our ethanol during our 2013 fiscal year was approximately 3% greater than during our 2012 fiscal year. Management attributes this increase in ethanol prices with increased ethanol demand and lower ethanol imports during our 2013 fiscal year compared to our 2012 fiscal year. The higher ethanol prices we experienced early in our 2013 fiscal year declined toward the end of our 2013 fiscal year due to lower corn and gasoline prices.

In addition to higher ethanol prices, we sold approximately 8% more gallons of ethanol during our 2013 fiscal year compared to the same period of 2012. Management attributes this increase in total production of ethanol with improved efficiency operating the ethanol plant during our 2013 fiscal year compared to the same period of 2012.

Our total distiller grains revenue was significantly higher during our 2013 fiscal year and the same period of 2012. Our total distiller grains revenue was approximately 16% greater during our 2013 fiscal year compared to the same period of 2012. We sold approximately 9% more tons of distiller grains during our 2013 fiscal year compared to the same period of 2012 due to our increased production during the 2013 period, partially offset by increased corn oil production during the 2013 period. When we increase the amount of corn oil we separate from our distillers grains, the total tons of distiller grains that we have to sell decreases by the volume of corn oil which is removed. The average prices we received for our distiller grains were higher during our 2013 fiscal year compared to the same period of 2012. The average price we received per ton of modified/wet distiller grains sold increased by approximately 1% during our 2013 fiscal year compared to the same period of 2012. The average price we received per ton of dried distiller grains sold increased by approximately 4% during our 2013 fiscal year compared to the same period of 2012. Management attributes these higher distiller grains prices to higher corn prices and decreased corn supplies during our first two quarters of 2013. However, distillers grains prices were decreasing during our fourth fiscal quarter of 2013 due to lower corn prices.

We had more revenue from corn oil sales during our 2013 fiscal year compared to the same period of 2012, due to the net effect of increased corn oil production offset by slightly lower corn oil prices. The average price we received for our corn oil during our 2013 fiscal year was approximately 7% less than the average price we received during the same period of 2012. Management attributes this decrease in corn oil prices with a combination of increased corn oil production along with relatively stable corn oil demand. Management also believes lower corn prices negatively impacted corn oil prices during our 2013 fiscal year. We produced approximately 16% more pounds of corn oil during our 2013 fiscal year compared to the same period of 2012. Management attributes this increase in corn oil production with increased production by the ethanol plant generally along with improved efficiency in operating the corn oil extraction equipment which increased the amount of corn oil we separated from each pound of distiller grains.

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Cost of Goods Sold

Our total cost of goods sold was approximately 4% greater during our 2013 fiscal year compared to the same period of 2012 due to increased corn and natural gas consumption and higher natural gas prices.

The average price we paid per bushel of corn, without taking into account derivative instruments, was approximately 3% lower during our 2013 fiscal year compared to our 2012 fiscal year. Management attributes this decrease in the average price we paid per bushel of corn with lower market corn prices during our third and fourth quarters of our 2013 fiscal year. Corn prices were higher during the beginning of our 2013 fiscal year due to lower corn supplies and unfavorable weather conditions during the local spring planting season. However, weather conditions improved during the summer of 2013 and the national corn crop harvested in the fall of 2013 was the largest corn crop on record. Our cost of goods sold was lower during our 2013 fiscal year due to $5.5 million in combined realized and unrealized gains on our risk management positions which reduced our cost of goods sold. By comparison, we had a combined realized and unrealized loss on our risk management positions which increased our cost of goods sold by approximately $4.2 million during our 2012 fiscal year. Losses, both realized and unrealized, that we experience on our corn derivative instruments increase our cost of goods sold.

We purchased approximately 10% more bushels of corn during our 2013 fiscal year compared to our 2012 fiscal year. Management attributes this increase in corn consumption with increased production during the 2013 period.

During our 2013 fiscal year, the average price we paid per MMBtu of natural gas was approximately 24% greater compared to our 2012 fiscal year. Management attributes this increase in natural gas prices to a longer and colder winter early in our 2013 fiscal year and a colder than usual November and December at the end of our 2013 fiscal year which resulted in increased natural gas demand and prices. In addition to the increase in natural gas prices was an increase in our total natural gas consumption of approximately 8% during our 2013 fiscal year compared to the same period of 2012. This increase in natural gas consumption was due to increased production at the ethanol plant.

Selling, General and Administrative Expenses

Our selling, general and administrative expenses were higher during our 2013 fiscal year compared to our 2012 fiscal year due primarily to legal expenses we have incurred related to the various lawsuits in which we were involved.

Other Income (Expense)

We had more other income during our 2013 fiscal year compared to the same period of 2012 due to having significantly less interest expense during the 2013 period because of our reduced debt load. We had less revenue from our investment in RPMG and our patronage dividend from CHS during our 2013 fiscal year compared to the same period of 2012. We had more interest income during our 2013 fiscal year compared to the same period of 2012 due to having more cash on hand during 2013.

Changes in Financial Condition for the Fiscal Year Ended December 31, 2014

Balance Sheet Data	December 31, 2014		December 31, 2013
Total current assets	$	78,792,392	$	56,456,056
Total property and equipment	105,218,605		113,502,166
Total other assets	4,496,076		4,119,904
Total Assets	$	188,507,073	$	174,078,126
Total current liabilities	$	40,237,858	$	39,627,710
Total long-term liabilities	419,904		15,303,526
Total members' equity	147,849,311		119,146,890
Total Liabilities and Members' Equity	$	188,507,073	$	174,078,126

We had less cash on hand at December 31, 2014 compared to December 31, 2013 due to our increased profitability during our 2014 fiscal year offset by distributions we made to our members during our 2014 fiscal year. In addition, we had approximately $32.2 million in marketable trading securities at December 31, 2014, a portion of which we are holding to complete the Retterath

26

unit repurchase. The value of our accounts receivable was lower at December 31, 2014 compared to December 31, 2013 due to the timing of a shipment of ethanol that occurred near the end of our 2014 fiscal year end along with lower prices for our products which impact the value of our accounts receivable. The value of our inventory was higher at December 31, 2014 compared to December 31, 2013 due primarily to an increase in the amount of corn inventory we had on hand at December 31, 2014. We also had more finished goods inventory at December 31, 2014 compared to December 31, 2013 due to an increase in the amount of ethanol we had on hand at the end of our 2014 fiscal year.

The value of our plant equipment and buildings was higher at December 31, 2014 compared to December 31, 2013 primarily due to installation of a new hammer mill during our 2014 fiscal year. Our net property and equipment was lower at December 31, 2014 compared to December 31, 2013 due to depreciation. We had approximately $441,000 in construction in progress at December 31, 2014 related to new pumps for corn oil and boiler water.

Our other assets were higher at December 31, 2014 compared to December 31, 2013 due to the investment we made in RPMG, LLC, an affiliate of our ethanol and corn oil marketer. Since we repaid all of our Home Federal loans, we no longer are amortizing our loan fees. We continue to amortize certain utility rights associated with construction of the ethanol plant.

Our accounts payable was higher at December 31, 2014 compared to December 31, 2013 primarily due to amounts we owed to RPMG, our ethanol and corn oil marketer. RPMG makes payments to us during each month based on an estimate of the selling price of our ethanol. When ethanol prices decrease significantly, like they did during December 2014, it results in an overpayment by our ethanol marketer which we are required to repay. This overpayment resulted in an increase in our accounts payable on December 31, 2014. We had a $30 million liability as of December 31, 2014 and 2013 related to the membership unit repurchase agreement. Our payroll payable was higher at the end of our 2014 fiscal year compared to the end of our 2013 fiscal year due to increased year-end bonuses during our 2014 fiscal year.

We had less long-term liabilities at December 31, 2014 compared to December 31, 2013 because we had no amounts outstanding on our long-term debt at December 31, 2014 compared to $15 million at December 31, 2013 which we borrowed to generate cash to offset the current liability related to the membership unit repurchase agreement.

Liquidity and Capital Resources

Our primary sources of liquidity are cash from our operations and our $20 million long-term revolving loan. Our credit facilities are described in greater detail below under "Short-Term and Long-Term Debt Sources." As of December 31, 2014, we had $20 million available pursuant to our revolving loans and approximately $32.5 million in cash. Based on financial forecasts performed by our management, we anticipate that we will have sufficient cash from our revolving loans and cash from our operations to continue to operate the ethanol plant at capacity for the next 12 months and beyond. 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 fiscal years ended December 31, 2014 and 2013:

	2014			2013
Net cash provided by operating activities	$	83,734,980		$	34,278,994
Net cash (used in) investing activities	(34,712,881		)	(3,409,186		)
Net cash (used in) provided by financing activities	(54,990,211		)	5,539,365
Cash at beginning of period	38,490,952			2,081,779
Cash at end of period	$	32,522,840		$	38,490,952

Cash Flow From Operations

Our operations generated significantly more cash during our 2014 fiscal year compared to the same period of 2013, primarily due to having significantly more net income during the 2014 fiscal year. We also experienced a significant change in our accounts receivable which provided cash for our operations during our 2014 fiscal year.

Cash Flow From Investing Activities

We used less cash for equipment and construction purchases during our 2014 fiscal year compared to our 2013 fiscal year because our only significant capital project during our 2014 fiscal year was installation of an additional hammer mill compared

27

to our grain bin construction project which was completed during our 2013 fiscal year. We had more earnings in our investments which were not distributed in cash during our 2014 fiscal year compared to our 2013 fiscal year, primarily due to our investment in RPMG. We also used cash to purchase approximately $32.2 million in trading securities during our 2014 fiscal year.

Cash Flow From Financing Activities

Financing activities used significantly more cash during our 2014 fiscal year compared to the same period of 2013 primarily due to cash we used to pay off our long-term debts during our 2014 fiscal year. We also made significant distributions to our members during our 2014 fiscal year. During our 2013 fiscal year, we received more cash from our long-term debt than we paid and we had a much smaller distribution of cash to our members.

The following table shows cash flows for the fiscal years ended December 31, 2013 and 2012:

	2013			2012
Net cash provided by operating activities	$	34,278,994		$	16,596,775
Net cash (used in) investing activities	(3,409,186		)	(1,856,031		)
Net cash provided by (used in) financing activities	5,539,365			(17,812,518		)
Cash at beginning of period	2,081,779			5,153,553
Cash at end of period	$	38,490,952		$	2,081,779

Cash Flow From Operations

Our operations generated significantly more cash during our 2013 fiscal year compared to the same period of 2012, primarily due to having significantly more net income during the 2013 fiscal year.

Cash Flow From Investing Activities

We used more cash for equipment and construction purchases during our 2013 fiscal year compared to our 2012 fiscal year due primarily to the grain bin construction project we completed during our 2013 fiscal year. We primarily used cash for the final payment we made on our corn oil system and installation of second generation relief valves on our fermentation tanks during our 2012 fiscal year.

Cash Flow From Financing Activities

Financing activities provided more cash during our 2013 fiscal year compared to the same period of 2012 primarily due to drawing additional funds from our revolving line of credit. We also used less cash for distributions during the 2013 period compared to the 2012 period.

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 and a security agreement in favor of Home Federal creating a senior lien on substantially all of our assets. We currently have a $20 million term revolving loan with Home Federal.

Term Revolving Loan

We have a $20 million term revolving loan which has a maturity date of August 1, 2018. Interest on the term revolving loan accrues at a rate equal to the one month LIBOR plus 310 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 balance of the term revolving loan becomes due. As of December 31, 2014, we had $0 outstanding on our term revolving loan and $20,000,000 available to be drawn. Interest accrued on our term revolving loan as of December 31, 2014 at a rate of 3.26% per year.

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2014 Term Loan

On February 24, 2014, we executed amended loan agreements with Home Federal pursuant to which Home Federal loaned us $15 million. The $15 million loan was structured as a term loan with a maturity date of March 1, 2019. The purpose of this term loan was to offset our liability associated with the Retterath repurchase agreement. The proceeds of this loan were placed in a separate account to fund the amounts due to Mr. Retterath pursuant to the repurchase agreement. Interest accrued on the term loan at an annual rate of 310 basis points in excess of LIBOR, adjusted monthly. We agreed to make equal monthly payments of principal and accrued interest of approximately $271,600. As of December 31, 2014, we had $0 outstanding on the term loan.

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 December 31, 2014, we were in compliance with all of our debt covenants and financial ratios. Our required financial covenants as of December 31, 2014 along with our calculated financial covenants as of December 31, 2014 are set forth below.

Covenant	Required Covenant at December 31, 2014			Actual Calculation at December 31, 2014
Working Capital	$	12,000,000		$	58,554,534
Tangible Net Worth	$	105,000,000		$	146,587,723
Tangible Owner's Equity	60		%	78		%

Management anticipates that we will be in compliance with all of our debt covenants and financial ratios for at least the next 12 months.

Failure to comply with the loan covenants or to 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 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 made in the loan agreements.

Contractual Cash Obligations

In addition to our long-term debt obligations, we have certain other contractual cash obligations and commitments. The following table provides information regarding our consolidated contractual obligations and approximate commitments as of December 31, 2014:

	Payment Due By Period
Contractual Cash Obligations	Total		Less than One Year		One to Three Years		Three to Five Years		After Five Years
Long-Term Debt Obligations	$	420,000	$	314,000	$	106,000	$	—	$	—
Operating Lease Obligations	4,343,000		1,663,000		2,680,000		—		—
Purchase Obligations	16,096,000		3,787,000		11,362,000		947,000		—
Total Contractual Cash Obligations	$	20,859,000	$	5,764,000	$	14,148,000	$	947,000	$	—

29

Application of Critical Accounting Estimates

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.  Of the significant accounting policies described in the notes to our financial statements, we believe that the following are the most critical:

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, distiller grains and corn oil are not specifically identifiable and as a result, revenue from the sale of ethanol, distiller grains and corn oil is recorded based on the net selling price reported to the Company from the marketer.

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.

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.

Off-Balance Sheet Arrangements

We do not have any off-balance sheet arrangements.

ITEM 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

We are exposed to the impact of market fluctuations associated with commodity prices as discussed below. We have no exposure to foreign currency risk as all of our business is conducted in U.S. Dollars and we had no amounts outstanding on variable interest debt as of December 31, 2014. We use derivative financial instruments as part of an overall strategy to manage market risk. We use cash, futures and option contracts to hedge changes to the commodity prices of corn, natural gas and ethanol. We do not enter into these derivative financial instruments for trading or speculative purposes, nor do we designate these contracts as hedges for accounting purposes.

Commodity Price Risk

We seek to minimize the risks from fluctuations in the prices of raw material inputs, such as corn and natural gas, and finished products, such as ethanol and distiller grains, through the use of hedging instruments. In practice, as markets move, we actively manage our risk and adjust hedging strategies as appropriate. Although we believe our hedge positions accomplish an economic hedge against our future purchases and sales, management has chosen not to use hedge accounting, which would match the gain or loss on our hedge positions to the specific commodity purchase being hedged. We are using fair value accounting for our hedge positions, which means as the current market price of our hedge positions changes, the realized or unrealized gains and

30

losses are immediately recognized in our cost of goods sold or as an offset to revenues. The immediate recognition of hedging gains and losses under fair value accounting can cause net income to be volatile from quarter to quarter due to the timing of the change in value of the derivative instruments relative to the cost and use of the commodity being hedged.

As of December 31, 2014, we had price protection in place for approximately 9% of our anticipated corn needs, 13% of our natural gas needs and approximately 4% of our ethanol sales for the next 12 months. A sensitivity analysis has been prepared to estimate our exposure to ethanol, corn and natural gas price risk. Market risk related to these factors is estimated as the potential change in income resulting from a hypothetical 10% adverse change in the average cost of our corn and natural gas prices and average ethanol price as of December 31, 2014, net of the forward and future contracts used to hedge our market risk for corn and natural gas usage requirements. The volumes are based on our expected use and sale of these commodities for a one year period from December 31, 2014. The results of this analysis, which may differ from actual results, are as follows:

	Estimated Volume Requirements for the next 12 months (net of forward and futures contracts)	Unit of Measure	Hypothetical Adverse Change in Price	Approximate Adverse Change to income
Natural Gas	3,132,000	MMBTU	10%	$	(1,274,724	)
Ethanol	130,560,000	Gallons	10%	(19,714,560		)
Corn	42,000,000	Bushels	10%	(16,044,000		)

For comparison purposes, our sensitivity analysis for our 2013 fiscal year is set forth below.

	Estimated Volume Requirements for the next 12 months (net of forward and futures contracts)	Unit of Measure	Hypothetical Adverse Change in Price	Approximate Adverse Change to income
Natural Gas	3,500,000	MMBTU	10%	$	(1,893,500	)
Ethanol	132,860,000	Gallons	10%	(23,914,800		)
Corn	44,000,000	Bushels	10%	(18,568,000		)

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PART 8.        FINANCIAL STATEMENTS

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Board of Directors and Members

Homeland Energy Solutions, LLC

We have audited the accompanying balance sheets of Homeland Energy Solutions, LLC as of December 31, 2014 and 2013, and the related statements of operations, changes in members' equity and cash flows for each of the three years in the period ended December 31, 2014. These financial statements are the responsibility of the Company's management. Our responsibility is to express an opinion on these financial statements based on our audits.

We conducted our audits in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. The Company is not required to have, nor were we engaged to perform, an audit of its internal control over financial reporting. Our audits included consideration of internal control over financial reporting as a basis for designing audit procedures that are appropriate in the circumstances, but not for the purpose of expressing an opinion on the effectiveness of the Company's internal control over financial reporting. Accordingly, we express no such opinion. An audit also includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements, assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audits provide a reasonable basis for our opinion.

In our opinion, the financial statements referred to above present fairly, in all material respects, the financial position of Homeland Energy Solutions, LLC as of December 31, 2014 and 2013, and the results of its operations and its cash flows for each of the three years in the period ended December 31, 2014 in conformity with U.S. generally accepted accounting principles.

Des Moines, Iowa

February 27, 2015

32

Homeland Energy Solutions, LLC

Balance Sheets

	December 31, 2014		December 31, 2013
ASSETS
CURRENT ASSETS
Cash and cash equivalents	$	32,522,840	$	38,490,952
Trading securities	32,220,801		—
Accounts receivable	1,248,484		7,484,886
Derivative instruments	1,304,697		1,180,775
Inventory	9,517,127		7,397,733
Prepaid and other	1,978,443		1,901,710
Total current assets	78,792,392		56,456,056
PROPERTY AND EQUIPMENT
Land and improvements	22,539,771		22,533,935
Buildings	5,528,027		5,366,168
Equipment	140,904,830		139,453,228
Construction in progress	440,875		108,577
	169,413,503		167,461,908
Less accumulated depreciation	64,194,898		53,959,742
Total property and equipment	105,218,605		113,502,166
OTHER ASSETS
Loan fees, net of amortization of $1,249,653 and $1,145,047	—		27,925
Utility rights, net of amortization of $1,046,441 and $910,053	1,261,588		1,397,976
Other assets	3,234,488		2,694,003
Total other assets	4,496,076		4,119,904
TOTAL ASSETS	$	188,507,073	$	174,078,126

See Notes to Financial Statements.

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Homeland Energy Solutions, LLC

Balance Sheets (continued)

	December 31, 2014		December 31, 2013
LIABILITIES AND MEMBERS' EQUITY
CURRENT LIABILITIES
Accounts payable	$	9,000,883	$	8,654,638
Due to former member	30,000,000		30,000,000
Interest payable	—		1,361
Property tax payable	483,036		464,524
Payroll payable	753,939		507,187
Total current liabilities	40,237,858		39,627,710
COMMITMENTS AND CONTINGENCIES
LONG-TERM LIABILITIES
Term revolving loan	—		15,000,000
Other liabilities	419,904		303,526
Total long-term liabilities	419,904		15,303,526
MEMBERS' EQUITY (64,585 and 64,585 units issued and outstanding as of December 31, 2014 and 2013, respectively)	147,849,311		119,146,890
TOTAL LIABILITIES AND MEMBERS' EQUITY	$	188,507,073	$	174,078,126

See Notes to Financial Statements.

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Homeland Energy Solutions, LLC

Statements of Operations

For the Years Ended December 31, 2014, 2013, and 2012

	December 31, 2014			December 31, 2013			December 31, 2012
Revenue	$	330,436,877		$	400,211,785		$	359,242,777
Costs of goods sold	257,680,689			368,758,166			356,064,736
Gross profit	72,756,188			31,453,619			3,178,041
Selling, general and administrative expenses	4,716,195			3,380,466			2,758,898
Operating income	68,039,993			28,073,153			419,143
Other income (expense)
Interest expense	(129,480		)	(60,230		)	(246,272		)
Interest income	23,460			11,506			820
Other income	681,978			209,479			321,074
Total other income (expense)	575,958			160,755			75,622
Net Income	$	68,615,951		$	28,233,908		$	494,765
Basic & diluted net income per capital unit	$	1,062.41		$	359.48		$	5.47
Distribution per capital unit	$	618.00		$	131.00		$	133.00
Weighted average number of units outstanding for the calculation of basic & diluted net income per capital unit	64,585			78,542			90,445

See Notes to Financial Statements.

35

Homeland Energy Solutions, LLC

Statements of Cash Flows

For the Years Ended December 31, 2014, 2013, and 2012

	Fiscal Year Ended			Fiscal Year Ended			Fiscal Year Ended
	December 31, 2014			December 31, 2013			December 31, 2012
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$	68,615,951		$	28,233,908		$	494,765
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	10,476,150			10,445,877			11,817,100
Unrealized loss (gain) on risk management activities	(123,922		)	160,506			259,437
Change in working capital components:
Accounts receivable	6,236,402			(5,099,248		)	1,010,396
Inventory	(2,119,394		)	2,257,999			845,702
Prepaid expenses and other	(76,733		)	36,256			309,158
Accounts payable and other accrued expenses	726,526			(1,756,304		)	1,860,217
Net cash provided by operating activities	83,734,980			34,278,994			16,596,775
CASH FLOWS FROM INVESTING ACTIVITIES
Purchase of trading securities	(32,220,801		)	—			—
Payments for equipment and construction in progress	(1,968,649		)	(2,399,329		)	(1,437,370		)
Proceeds from sale of equipment	17,054			—			—
Increase in other assets	(540,485		)	(1,009,857		)	(593,348		)
Decrease in restricted cash	—			—			174,687
Net cash (used in) investing activities	(34,712,881		)	(3,409,186		)	(1,856,031		)
CASH FLOWS FROM FINANCING ACTIVITIES
Distribution to members	(39,913,530		)	(8,460,635		)	(12,029,185		)
Payments for debt issuance costs	(76,681		)	—			—
Proceeds from long-term borrowings	30,000,000			130,350,000			24,750,000
Payments on long-term borrowings	(45,000,000		)	(116,350,000		)	(30,533,333		)
Net cash provided by (used in) financing activities	(54,990,211		)	5,539,365			(17,812,518		)
Net increase (decrease) in cash	(5,968,112		)	36,409,173			(3,071,774		)
Cash and Cash Equivalents - Beginning	38,490,952			2,081,779			5,153,553
Cash and Cash Equivalents - Ending	$	32,522,840		$	38,490,952		$	2,081,779
SUPPLEMENTAL DISCLOSURES OF CASH FLOW INFORMATION
Cash paid for interest, net of capitalized interest of none, none, and none, respectively	$	130,841		$	61,381		$	256,727
SUPPLEMENTAL SCHEDULE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Equity adjustment in investee	$	—		$	—		$	215,610
Accounts payable related to property and equipment	$	—		$	213,989		$	—
Commitment to redeem membership units	$	—		$	30,000,000		$	—

See Notes to Financial Statements.

36

Homeland Energy Solutions, LLC

Statement of Members' Equity

For the Years ended December 31, 2014, 2013 and 2012

	Members
	Equity
Balance, December 31, 2010	$	112,483,814
Redemption of 1,000 membership units	(1,000,000		)
Distributions	(7,145,155		)
Net Income	36,353,768
Balance, December 31, 2011	140,692,427
Equity adjustment in investee	215,610
Distributions	(12,029,185		)
Net Income	494,765
Balance, December 31, 2012	129,373,617
Committed 25,860 membership units to be redeemed	(30,000,000		)
Distributions	(8,460,635		)
Net Income	28,233,908
Balance, December 31, 2013	119,146,890
Distributions	(39,913,530		)
Net Income	68,615,951
Balance, December 31, 2014	$	147,849,311

See Notes to Financial Statements.

37

Homeland Energy Solutions, LLC

Notes to Financial Statements

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. The Company has capacity to produce in excess of 135 million gallons annually and sells distillers dried grains and corn oil as byproducts of ethanol production.

Organization

Homeland Energy Solutions, LLC is organized as an Iowa limited liability company. The members' liability is limited as specified in Homeland Energy Solutions' operating agreement and pursuant to the Iowa Revised Uniform Limited Liability Company Act.

Significant Accounting Policies:

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.

Cash and Cash Equivalents

The Company maintains its accounts primarily at one financial institution. At various times, the Company's cash balances may exceed amounts insured by the Federal Deposit Insurance Corporation. The Company has not experienced losses in such accounts.

Trading Securities

Investments bought and held principally for the purpose of selling them in the the near term are classified as trading securities. Trading securities are measured at fair value using prices obtained from pricing services. Any unrealized or realized gains and losses on the trading securities are recorded as part of other income (expense).

At December 31, 2014, trading securities consisted of short term bond mutual funds with an approximate cost of $32,201,000 and fair value of $32,221,000. For the fiscal year ended December 31, 2014, the Company recorded a net unrealized gain of approximately $20,000 from these investments as part of other income (expense). There were no trading securities held as of December 31, 2013.

The Board of Directors voted to set aside up to $30 million in trading securities that will be used by the Company for the repurchase of 25,860 membership units held by Steve Retterath per the terms of an agreement with Mr. Retterath entered into on June 13, 2013 by the Company.

Receivables

Credit sales are made primarily to one customer and no collateral is required. The Company carries these accounts receivable at face amount with no allowance for doubtful accounts due to the historical collection rates on these accounts.

Investments

The Company has a less than 20% investment interest in Renewable Products Marketing Group, LLC. This investment is being accounted for under the equity method of accounting under which the Company's share of net income is recognized as income in the Company's income statement and added to the investment account. The investment balance is included in other assets and the income recognized as other income. The investment is evaluated for indications of impairment on a regular basis, a loss would be recognized when the fair value is determined to be less than the carrying value.

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.

38

Homeland Energy Solutions, LLC

Notes to Financial Statements

Property and Equipment

The Company incurred site selection and plan development costs on the proposed site that were capitalized. Significant additions, betterments and costs to acquire land options are capitalized, while expenditures for maintenance and repairs are charged to operations when incurred. Property and equipment are stated at cost. The Company uses the straight-line method of computing depreciation over the estimated useful lives as follows.

	Estimated Useful Life in Years
	Minimum	Maximum
Land Improvements	20	40
Buildings	10	40
Equipment	7	40

Land improvements relate to two general categories: road infrastructure and general sitework. Road infrastructure relates to the excavating and paving of surface roads and the sitework includes such things as the well system and earthmoving. Buildings relate to three general categories: grain handling, process and administrative buildings. Equipment relates to three general categories: mechanical equipment, rail handling equipments and administrative and maintenance equipment. Mechanical equipment generally relates to equipment for handling inventories and the production of ethanol and related products, including such things as boilers, cooling towers, grain bins, centrifuges, conveyors, fermentation tanks, pumps and drying equipment. Rail handling equipments relates to railroad track. Administrative and maintenance equipment includes vehicles, computer systems, security equipments, testing devices and shop equipment.

The Company reviewed its usage, continued maintenance and productivity of its processing and production equipment, based on this review the Company reevaluated the useful lives of such equipment. As such, effective October 1, 2012 the Company increased the estimated useful lives on a significant portion of its processing and production equipment from 10 to 15 years. This change in estimate is accounted for on a prospective basis. This change resulted in a decrease in depreciation expense, an increase to operating income and an increase in net income of approximately $750,000, and an increase in income per unit of $8.29 for the Fourth Quarter 2012.

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 in 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. The Company has concluded that no impairment is 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.

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.

39

Homeland Energy Solutions, LLC

Notes to Financial Statements

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.

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 were amortized over the term of the loan and utility rights are amortized over 15 years or the anticipated useful life utilizing a method that materially approximates the straight-line method. 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.

At December 31, 2014, the Company anticipates the following amortization of Utility Rights for the twelve month periods ended December 31:

2015	$	136,000
2016	136,000
2017	136,000
2018	136,000
2019	136,000
Thereafter	580,000
Total amortization	$	1,260,000

Revenue and Cost 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. The 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. Rail car lease costs incurred by the Company in the sale and shipment of distiller grain products are included in the cost of goods sold.

Income Taxes

The Company was formed under sections of the federal and state income tax laws which provide that, in lieu of corporate income taxes, the members separately account for their share of the Company's items of income, deductions, losses and credits. As a result of this election, no income taxes have been recognized in the accompanying financial statements.

Management has evaluated the Company's tax positions under the Financial Accounting Standards Board issued guidance on accounting for uncertainty in income taxes and concluded that the Company had taken no uncertain tax positions that require adjustment to the financial statements to comply with the provisions of this guidance. Generally, the Company is no longer subject to income tax examinations by the U.S. federal, state or local authorities for the years before 2011.

Committed Shares to be Redeemed

On June 13, 2013, the Company entered into an agreement with Steve Retterath, the Company's largest member, to repurchase and retire all of the membership units owned by Mr. Retterath. The Company agreed to close on this repurchase on or before August 1, 2013. The Company agreed to repurchase and retire 25,860 membership units owned by Mr. Retterath in exchange for $30 million, to be paid in two equal installments payable at closing and on July 1, 2014. The transaction failed to close by the scheduled date due to objections by Mr. Retterath. Due to all conditions of the agreement being met prior to, or on, August 1, 2013, the Company believes that it has a binding agreement with Mr. Retterath; as such the commitment to repurchase and retire the membership units is reflected in the financial statements as if the transaction had closed on August 1, 2013.

40

Homeland Energy Solutions, LLC

Notes to Financial Statements

Net Income 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 per unit are the same.

Prior to, or on, August 1, 2013, the Company believes it has a binding agreement with Steve Retterath to repurchase and retire all 25,860 membership units owned by Mr. Retterath. These membership units have thus been excluded in the determination of net income per unit as presented in the Statement of Operations. The Company is currently involved in litigation with Mr. Retterath. There is potential that Mr. Retterath will continue as a unit holder upon conclusion of the litigation and said membership units would not be redeemed under the repurchase agreement. If the units are not redeemed, basic and diluted net income per unit, including the 25,860 units, for the three and twelve months ended December 31, 2014 would be $138.51 and $758.65, respectively.

Environmental Liabilities

The Company's operations are subject to environmental laws and regulations adopted by various governmental authorities in the jurisdiction in which it operates. These laws require the Company to investigate and remediate the effects of the release or disposal of materials at its locations. Accordingly, the Company has adopted policies, practices and procedures in the areas of pollution control, occupational health and the production, handling, storage and use of hazardous materials to prevent material environmental or other damage, and to limit the financial liability which could result from such events. Environmental liabilities are recorded when the Company's liability is probable and the costs can be reasonably estimated. No expense or liability, including asset retirement obligations, for environmental liabilities has been recorded for the years ended December 31, 2014, 2013, or 2012.

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. For the twelve months ended December 31, 2014, ethanol sales averaged approximately 79% of total revenues, while approximately 18% of revenues were generated from the sale of distiller grains and 3% of revenues were generated from the sale of corn oil. For the twelve months ended December 31, 2014, corn costs averaged approximately 78% of cost of goods sold.

The Company's operating and financial performance is largely driven by the prices at which it sells 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, in general, for less than gasoline at the wholesale level. Excess ethanol supply in the market, in particular, puts downward pressure on the price of ethanol. The Company's largest cost of production is corn. The cost of corn is generally impacted by factors such as supply and demand, weather, and government policies and programs. The Company's risk management program is used to protect against the price volatility of these commodities.

2.    INVENTORY

Inventory consisted of the following as of December 31, 2014 and 2013.

	December 31, 2014		December 31, 2013
Raw Materials	$	5,962,251	$	4,617,404
Work in Process	1,402,369		1,600,041
Finished Goods	2,152,507		1,180,288
Totals	$	9,517,127	$	7,397,733

41

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 Company currently has a term revolving loan with Home Federal.

Term Revolving Loan

Under the terms of the Seventh Amendment to the Master Loan Agreement, the Company has a $20 million term revolving loan which has a maturity date of August 1, 2018. Interest on the term revolving loan accrues at a rate equal to the one month LIBOR plus 310 basis points, 3.26% on December 31, 2014. The Company is required to make monthly payments of interest until the maturity date of the term revolving loan on August 1, 2018, on which date the unpaid principal balance of the term revolving loan becomes due. The balance outstanding on the term revolving loan as of December 31, 2014 and December 31, 2013 was $0 and $15,000,000 respectively.

2014 Term Loan

Under the terms of the Fourth Supplement to the Master Loan Agreement, dated February 28, 2014, the Company had a $15 million term loan which had a maturity date of March 1, 2019. Interest on the term loan accrued at a rate equal to the one month LIBOR plus 310 basis points, 3.26% on December 31, 2014. The Company was required to make equal monthly payments of principal and accrued interest in an amount equal to $271,614 per month, or such greater or lesser amount determined by the lender to fully amortize the principal balance of the term loan over the period of five years. The 2014 term loan was paid in full by the Company on June 18, 2014 and the outstanding principal balance on the term loan as of December 31, 2014 was $0.

Covenants

In addition, during the term of the Loans, the Company is subject to certain financial covenants at various times calculated monthly, quarterly or annually, including restriction of the payment of dividends and capital expenditures and maintenance of certain financial ratios including the minimum working capital, tangible net worth, and a fixed charge ratio as defined by the Master Loan Agreement. 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.

4.    RELATED PARTY TRANSACTIONS

Due to Former Member

On June 13, 2013, the Company entered into an agreement with Steve Retterath, the Company's largest member, to repurchase and retire all of the units owned by Mr. Retterath. The Company agreed to close on this repurchase on or before August 1, 2013. The Company agreed to repurchase and retire 25,860 memberships units owned by Mr. Retterath in exchange for $30 million, to be paid in two equal installments payable at closing and on July 1, 2014. The transaction failed to close by the scheduled date due to objections by Mr. Retterath. The Company believes that it has a binding agreement with Mr. Retterath. On August 14, 2013, the Company filed a lawsuit against Mr. Retterath in Iowa state court to enforce the terms of the repurchase agreements. The Company is asking the Iowa court to require Mr. Retterath to complete the repurchase agreement pursuant to its terms.

Mr. Retterath contends that he is not bound by the agreement. The Company's position is as of the closing date, Mr. Retterath is no longer the equitable owner of any membership units in the Company. As a result, the Company has recorded a $30 million short-term liability related to the amount the Company agreed to pay Mr. Retterath to repurchase his membership units and has correspondingly reduced members' equity on its balance sheet. If the Company is ultimately unsuccessful in its lawsuit against Mr. Retterath, the Company will reevaluate the accounting considerations made during the period of time that the lawsuit is pending.

Other Matters

The Company purchases corn and materials from members of its Board of Directors who own or manage elevators or are local producers of corn. Purchases during the years ended December 31, 2014, 2013 and 2012 from these companies and individuals totaled approximately $4,187,000, $4,347,000 and $0, respectively. Amounts due to those members was $0 as of December 31, 2014 and 2013.

Homeland Energy Solutions, LLC

Notes to Financial Statements

Previously, the Company had an agreement with Golden Grain Energy, LLC (Golden Grain), a member of the Company, for management services. Pursuant to the agreement, Homeland Energy and Golden Grain 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. This agreement was terminated on May 16, 2014. For the years ended December 31, 2014, 2013, and 2012 the Company incurred net costs of approximately $47,000, $139,000 and $119,000, respectively related to this agreement.

5.    COMMITMENTS, CONTINGENCIES AND AGREEMENTS

Ethanol, corn oil, and distiller grains marketing agreements and major customers

The Company has entered into a marketing agreement with RPMG, a related party, to sell all ethanol produced at the plant to an entity in which the Company invests in at a mutually agreed on price, less commission and transportation charges. As of December 31, 2014, the Company had commitments to sell approximately 14,000,000 gallons at various fixed prices and 21,000,000 gallons at basis price levels indexed against exchanges for delivery through March 31, 2015.

The Company has entered into a marketing agreement with RPMG to sell all corn oil produced at the plant at a mutually agreed on price, less marketing fees and transportation charges. As of December 31, 2014, the Company had commitments to sell approximately 2,000,000 pounds at various fixed and basis price levels indexed against exchanges for delivery through January 31, 2015.

The Company also has an investment in RPMG, LLC, included in other assets, totaling approximately $2,646,000 and $2,305,000 as of December 31, 2014 and 2013.

The Company has entered into a marketing agreement to sell all distiller grains produced at the plant to CHS, 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, 2014. The agreement calls for automatic renewal for successive one-year terms unless 90-day prior written notice is given before the current term expires. As of December 31, 2014, the Company had approximately 56,000 tons of distiller grains commitments for delivery through June 2015 at various fixed prices.

Sales and marketing fees related to the agreements in place for the years ended December 31, 2014, 2013 and 2012 were as follows:

	2014			2013		2012
Sales ethanol - RPMG	$	262,029,000		$	305,444,000	$	276,321,000
Sales distiller grains	59,715,000			82,552,000		71,272,000
Sales corn oil - RPMG	8,976,000			12,558,000		11,649,000
Marketing fees ethanol - RPMG	$	141,000		$	225,000	$	392,000
Marketing fees distiller grains	722,000			744,000		723,000
Marketing fees corn oil - RPMG	46,000			67,000		67,000
	2014			2013		2012
Amount due from/(to) RPMG	$	(1,495,000	)	$	5,245,000	$	199,000
Amount due from CHS	595,000			2,147,000		2,077,000

At December 31, 2014, the Company had approximately $16,371,000 in outstanding corn purchase commitments for bushels at various prices and approximately 2,464,000 bushels of unpriced corn through March 2016 accounted for under the normal purchase exclusion.

The Company has commitments for minimum purchases of various utilities such as natural gas and electricity over the next 5 years, accounted for under the normal purchase exclusion, which are anticipated to approximate the following for the twelve month periods ending December 31:

43

Homeland Energy Solutions, LLC

Notes to Financial Statements

2015	$	3,787,000
2016	3,787,000
2017	3,787,000
2018	3,787,000
2019	947,000
Total anticipated commitments	$	16,095,000

6.    LEASE OBLIGATIONS

The Company leases rail cars and rail moving 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 years ended December 31, 2014, 2013 and 2012 was approximately $1,664,000, $1,665,000 and $1,334,000.

At December 31, 2014, the Company had the following approximate minimum rental commitments under non-cancelable operating leases for the twelve month periods ended December 31:

2015	$	1,663,000
2016	1,663,000
2017	861,000
2018	156,000
Total lease commitments	$	4,343,000

7.    EMPLOYEE BENEFIT PLANS

The Company has adopted a Simple IRA Adoption Agreement which provides retirement savings options for all eligible employees. Employees meeting certain eligibility requirements can participate in the plan. The Company makes a matching contribution based on the participants' eligible wages. For the years ended December 31, 2014, 2013 and 2012 the Company made matching contributions of approximately $77,000, $64,000 and $69,000, respectively.

8.    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 the 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 46 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 December 31, 2014, the Company has hedged portions of its anticipated monthly purchases for corn averaging approximately 9% 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, as amended and, therefore, are not marked to market in the Company's financial statements. The following table represents the approximate amount of realized and unrealized gains (losses) and changes in fair value recognized in earnings

44

Homeland Energy Solutions, LLC

Notes to Financial Statements

on commodity contracts for periods ended December 31, 2014, 2013, and 2012 and the fair value of derivatives as of December 31, 2014 and 2013:

	Income Statement Classification	Realized Gain (Loss)			Change In Unrealized Gain (Loss)			Total Gain (Loss)
Derivatives not designated as hedging instruments: Commodity contracts for the year ended December 31, 2014.
	Cost of Goods Sold	$	4,698,000		$	(185,000	)	$	4,513,000
	Revenue	(283,000		)	283,000			—
	Total	$	4,415,000		$	98,000		$	4,513,000
Derivatives not designated as hedging instruments: Commodity contracts for the year ended December 31, 2013.
	Cost of Goods Sold	$	5,915,000		$	(437,000	)	$	5,478,000
	Revenue	(60,000		)	(283,000		)	(343,000		)
	Total	$	5,855,000		$	(720,000	)	$	5,135,000
Derivatives not designated as hedging instruments: Commodity contracts for the year ended December 31, 2012.
	Cost of Goods Sold	$	(5,152,000	)	$	999,000		$	(4,153,000	)

	Balance Sheet Classification	December 31, 2014			December 31, 2013
Futures and option contracts through December 2015
In gain position		$	292,000		$	251,000
In loss position		(224,000		)	(283,000		)
Cash held by broker		1,237,000			1,213,000
	Current Asset	$	1,305,000		$	1,181,000

9.    FAIR VALUE MEASUREMENTS

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.

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:

45

Homeland Energy Solutions, LLC

Notes to Financial Statements

Trading securities: Trading securities consisting of mutual funds, corporate bonds, and certificates of deposit are reported at fair value utilizing Level 1 inputs. Trading securities are measured at fair value using prices obtained from pricing services.

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 December 31, 2014 and December 31, 2013, 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
Trading Securities
December 31, 2014
Assets	$	32,221,000		$	32,221,000		$	—	$	—
Derivative financial instruments
December 31, 2014
Assets	$	292,000		$	292,000		$	—	$	—
Liabilities	(224,000		)	(224,000		)	—		—
December 31, 2013
Assets	$	251,000		$	251,000		$	—	$	—
Liabilities	(283,000		)	(283,000		)	—		—

10.    LITIGATION MATTERS

Retterath

In relation to the repurchase agreement discussed in Note 4, on August 1, 2013 Mr. Retterath filed a lawsuit against the Company along with several directors, the Company's former CEO, CFO, Plant Manager, a former director and the Company's outside legal counsel in Florida state court. Mr. Retterath's factual basis for his claims is unclear from the complaint and amended complaints Mr. Retterath has filed, however, it appears that Mr. Retterath is claiming that certain actions taken by the Company violated fiduciary duties owed to him as a member or fraudulently induced him to take certain actions. Mr. Retterath is also claiming violations of state and federal securities laws and violations of Florida's deceptive and unfair trade practices statutes. On August 14, 2013, the Company filed a lawsuit in Iowa state court to enforce the repurchase agreement the Company entered into with Mr. Retterath.

GS Cleantech Corporation

On August 9, 2013, GS Cleantech Corporation (GS Cleantech), a subsidiary of Greenshift Corporation, filed a complaint against the Company alleging that the Company's operation of a corn oil extraction process licensed by the Company infringes patent rights claimed by GS Cleantech. GS Cleantech seeks royalties, damages and potentially triple damages associated with the alleged infringement, as well as attorney's fees from the Company. The Company filed a motion for summary judgment which was granted by the Court. The Company expects GS Cleantech will appeal this decision. The Company has filed an answer and counterclaims claiming invalidity of the patents, noninfringement, and inequitable conduct. The Company is not currently able to predict the outcome of the litigation with any degree of certainty.

46

Homeland Energy Solutions, LLC

Notes to Financial Statements

11.    QUARTERLY FINANCIAL DATA (UNAUDITED)

Summary quarterly results for the years ended December 31, 2014, 2013 and 2012 are as follows:

2014	First Quarter		Second Quarter		Third Quarter			Fourth Quarter
Total Revenues	$	81,752,306	$	87,823,949	$	83,212,628		$	77,647,934
Gross Profit	15,439,851		23,036,031		20,393,602			13,865,303
Operating Income	14,437,092		22,044,490		19,199,400			12,359,011
Net Income	14,695,363		22,145,502		19,247,197			12,527,889
Basic & diluted earnings per unit	$	227.54	$	342.89	$	298.01		$	193.98
2013	First Quarter		Second Quarter		Third Quarter			Fourth Quarter
Total Revenues	$	97,975,795	$	112,243,015	$	98,342,436		$	91,650,539
Gross Profit	3,157,969		8,613,215		5,614,185			14,068,250
Operating Income	2,440,555		7,944,088		4,939,290			12,749,220
Net Income	2,478,297		8,038,058		5,062,318			12,655,235
Basic & diluted earnings per unit	$	27.40	$	88.87	$	73.28		$	195.95
2012	First Quarter		Second Quarter		Third Quarter			Fourth Quarter
Total Revenues	$	92,011,614	$	93,780,274	$	84,499,206		$	88,951,683
Gross Profit (Loss)	2,367,009		1,896,219		(1,769,920		)	684,733
Operating Income (Loss)	1,594,601		1,240,174		(2,416,309		)	677
Net Income (Loss)	1,645,659		1,221,495		(2,467,293		)	94,904
Basic & diluted earnings (loss) per unit	$	18.20	$	13.51	$	(27.28	)	$	1.05

12.    SUBSEQUENT EVENTS

On February 17, 2015, the Company's board of directors declared a cash distribution of $9,816,920 to be paid to 64,585 membership units which equals $152 per membership unit. The record date for the distribution was February 17, 2015. The Company anticipates paying this distribution in March 2015. No distribution will be paid by the Company to Steve Retterath.

ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND FINANCIAL DISCLOSURE.

None.

ITEM 9A. CONTROLS AND PROCEDURES.

Disclosure Controls and Procedures

Management of Homeland Energy is responsible for maintaining disclosure controls and procedures that are designed to ensure that information required to be disclosed in the reports that we file or submit under the Securities Exchange Act of 1934 (the "Exchange Act") are recorded, processed, summarized and reported within the time periods specified in the Securities and Exchange Commission's rules and forms. In addition, the disclosure controls and procedures must ensure that such information is accumulated and communicated to the Company's management, including its Chief Executive Officer and Chief Financial Officer, as appropriate, to allow timely decisions regarding required financial and other required disclosures.

As of the end of the period covered by this report, an evaluation of the effectiveness of our disclosure controls and procedures (as defined in Rules 13(a)-15(e) and 15(d)-15(e) of the Exchange Act) was carried out under the supervision and with

47

the participation of our Chief Executive Officer (the principal executive officer), Patrick Boyle, and our Chief Financial Officer (the principal financial and accounting officer), David A. Finke. Based on their evaluation of our disclosure controls and procedures, they have concluded that such disclosure controls and procedures were effective as of December 31, 2014 to ensure that information required to be disclosed in the reports that we file or submit under the Exchange Act are recorded, processed, summarized and reported within the time periods required by the forms and rules of the Securities and Exchange Commission; and to ensure that the information required to be disclosed by an issuer in the reports that it files or submits under the Exchange Act is accumulated and communicated to our management including our principal executive and principal financial officers, or persons performing similar functions, as appropriate to allow timely decisions regarding required disclosure.

Internal Control Over Financial Reporting

Inherent Limitations Over Internal Controls

Our internal control over financial reporting is designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles. Our internal control over financial reporting includes those policies and procedures that:

    (i)    pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of our assets;

    (ii)    provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with generally accepted accounting principles, and that our receipts and expenditures are being made only in accordance with authorizations of our management and directors; and

    (iii)    provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use, or disposition of our assets that could have a material effect on the financial statements.

Management, including our Chief Executive Officer and Chief Financial Officer, does not expect that our internal controls will prevent or detect all errors and all fraud. A control system, no matter how well designed and operated, can provide only reasonable, not absolute, assurance that the objectives of the control system are met. Further, the design of a control system must reflect the fact that there are resource constraints, and the benefits of controls must be considered relative to their costs. Because of the inherent limitations in all control systems, no evaluation of internal controls can provide absolute assurance that all control issues and instances of fraud, if any, have been detected. Also, any evaluation of the effectiveness of controls in future periods is subject to the risk that those internal controls may become inadequate because of changes in business conditions, or that the degree of compliance with the policies or procedures may deteriorate.

Management's Annual Report on Internal Control over Financial Reporting

Our management is responsible for establishing and maintaining adequate internal control over financial reporting (as defined in Rule 13a-15(f) under the Securities Exchange Act of 1934, as amended). Management conducted an evaluation of the effectiveness of our internal control over financial reporting based on the criteria set forth in the 1992 Internal Control-Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission ("COSO"). Based on this evaluation, management has concluded that our internal control over financial reporting was effective as of December 31, 2014.

This annual report does not include an attestation report of our registered public accounting firm regarding internal control over financial reporting. As we are a non-accelerated filer, management's report is not subject to attestation by our registered public accounting firm.

This report shall not be deemed to be filed for purposes of Section 18 of the Securities Exchange Act of 1934, or otherwise subject to the liabilities of that section , and is not incorporated by reference into any filing of the Company, whether made before or after the date hereof, regardless of any general incorporation language in such filing.

Changes in Internal Controls

There were no changes in our internal control over financial reporting during the fourth quarter of our 2014 fiscal year, which were identified in connection with management's evaluation required by paragraph (d) of rules 13a-15 and 15d-15 under the Exchange Act, that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

48

ITEM 9B. OTHER INFORMATION.

None.

PART III

ITEM 10. DIRECTORS, EXECUTIVE OFFICERS AND CORPORATE GOVERNANCE

The information required by this Item is incorporated by reference in the definitive proxy statement from our 2015 annual meeting of members to be filed with the Securities and Exchange Commission within 120 days after our 2014 fiscal year end on December 31, 2014. This proxy statement is referred to in this report as the 2015 Proxy Statement.

ITEM 11. EXECUTIVE COMPENSATION.

The information required by this Item is incorporated by reference to the 2015 Proxy Statement.

ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT AND RELATED STOCKHOLDER MATTERS.

The information required by this Item is incorporated by reference to the 2015 Proxy Statement.

ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS, AND DIRECTOR INDEPENDENCE.

The information required by this Item is incorporated by reference to the 2015 Proxy Statement.

ITEM 14. PRINCIPAL ACCOUNTING FEES AND SERVICES.

The information required by this Item is incorporated by reference to the 2015 Proxy Statement.

49

PART IV

ITEM 15. EXHIBITS, FINANCIAL STATEMENT SCHEDULES.

Exhibits Filed as Part of this Report and Exhibits Incorporated by Reference.

The following exhibits and financial statements are filed as part of, or are incorporated by reference into, this report:

(1) Financial Statements

The financial statements appear beginning at page 33 of this report.

(2) Financial Statement Schedules

All supplemental schedules are omitted as the required information is inapplicable or the information is presented in the financial statements or related notes.

(3) Exhibits

Exhibit No.	Exhibit	Filed Herewith	Incorporated by Reference
3.1	Articles of Organization of the registrant.		Exhibit 3.1 to the registrant's registration statement on Form SB-2 (Commission File 333-135967).
3.2	Certificate of Name Change and Corresponding Amendment to Articles of Organization.		Exhibit 3.2 to the registrant's registration statement on Form SB-2 (Commission File 333-135967).
3.3	Operating Agreement of the registrant.		Exhibit 3.3 to the registrant's registration statement on Form SB-2 (Commission File 333-135967).
3.4	First Amendment to Operating Agreement of the registrant dated November 14, 2006.		Exhibit 3.4 to Pre-Effective Amendment No. 3 to the registrant's registration statement on Form SB-2 (Commission File 333-135967).
3.5	Amended and Restated Operating Agreement dated April 4, 2013.		Exhibit 3.1 to the registrant's Form 10-Q filed with the Commission on May 15, 2013.
3.6	First Amendment to Amended and Restated Operating Agreement dated December 19, 2013.		Exhibit 3.6 to the registrant's Form 10-K filed with the Commission on February 27, 2014.
4.1	Form of Membership Unit Certificate.		Exhibit 4.2 to the registrant's registration statement on Form SB-2 (Commission File 333-135967).
10.1	License Agreement dated August 1, 2007 between Homeland Energy Solutions and ICM, Inc.		Exhibit 10.26 to the registrant's Form 10-QSB filed with the Commission on August 14, 2007.
10.2	Master Loan Agreement dated November 30, 2007 between Homeland Energy Solutions, LLC and Home Federal Savings Bank.		Exhibit 10.30 to the registrant's Form 10-KSB filed with the Commission on February 22, 2008.
10.3	First Supplement to the Master Loan Agreement dated November 30, 2007 between Homeland Energy Solutions, LLC and Home Federal Savings Bank.		Exhibit 10.31 to the registrant's Form 10-KSB filed with the Commission on February 22, 2008.
10.4	Second Supplement to the Master Loan Agreement dated November 30, 2007 between Homeland Energy Solutions, LLC and Home Federal Savings Bank.		Exhibit 10.32 to the registrant's Form 10-KSB filed with the Commission on February 22, 2008.
10.5	Third Supplement to the Master Loan Agreement dated November 30, 2007 between Homeland Energy Solutions, LLC and Home Federal Savings Bank.		Exhibit 10.33 to the registrant's Form 10-KSB filed with the Commission on February 22, 2008.

50

10.6	Construction Note dated November 30, 2007 between Homeland Energy Solutions, LLC and Home Federal Savings Bank.	Exhibit 10.34 to the registrant's Form 10-KSB filed with the Commission on February 22, 2008.
10.7	Term Revolving Note dated November 30, 2007 between Homeland Energy Solutions, LLC and Home Federal Savings Bank.	Exhibit 10.35 to the registrant's Form 10-KSB filed with the Commission on February 22, 2008.
10.8	Revolving Line of Credit Note dated November 30, 2007 between Homeland Energy Solutions, LLC and Home Federal Savings Bank.	Exhibit 10.36 to the registrant's Form 10-KSB filed with the Commission on February 22, 2008.
10.9	Mortgage dated November 30, 2007 between Homeland Energy Solutions, LLC and Home Federal Savings Bank.	Exhibit 10.37 to the registrant's Form 10-KSB filed with the Commission on February 22, 2008.
10.10	Security Agreement dated November 30, 2007 between Homeland Energy Solutions, LLC and Home Federal Savings Bank.	Exhibit 10.38 to the registrant's Form 10-KSB filed with the Commission on February 22, 2008.
10.11	Disbursing Agreement dated November 30, 2007 between Homeland Energy Solutions, LLC and Home Federal Savings Bank.	Exhibit 10.39 to the registrant's Form 10-KSB filed with the Commission on February 22, 2008.
10.12	Second Amendment to the Lump Sum Design-Build Agreement dated July 6, 2007 between Homeland Energy Solutions and Fagen, Inc.	Exhibit 10.40 to the registrant's Form 10-KSB filed with the Commission on February 22, 2008.
10.13	Agreement for Private Development between Homeland Energy Solutions, LLC and Chickasaw County, Iowa dated December 18, 2007.	Exhibit 10.42 to the registrant's Form 10-KSB/A filed with the Commission on May 15, 2008.
10.14	Iowa Department of Transportation Application Form for RISE: Immediate Opportunity Project Funding for Homeland Energy Solutions, LLC dated August 20, 2007.	Exhibit 10.44 to the registrant's Form 10-KSB/A filed with the Commission on May 15, 2008.
10.15	Engineering, Procurement, and Construction Agreement between Homeland Energy Solutions, LLC and Cornerstone Energy, LLC d/b/a Constellation New Energy - CEI, LLC dated December 4, 2007. +	Exhibit 10.45 to the registrant's Form 10-KSB/A filed with the Commission on May 15, 2008.
10.16	Master Natural Gas Agreement and Base Agreement between Homeland Energy Solutions, LLC and Cornerstone Energy, LLC d/b/a Constellation NewEnergy - Gas Division CEI, LLC dated December 4, 2007. +	Exhibit 10.46 to the registrant's Form 10-KSB/A filed with the Commission on May 15, 2008.
10.17	Distillers Grain Marketing Agreement with CHS, Inc. dated August 8, 2008.	Exhibit 10.2 to the registrant's Form 10-Q filed with the Commission on August 14, 2008.
10.18	Rail Facilities Agreement with R & R Contracting dated July 24, 2008.	Exhibit 10.3 to the registrant's Form 10-Q filed with the Commission on August 14, 2008.
10.19	Customer Agreement with ADM Investor Services, Inc. dated July 29, 2008.	Exhibit 10.4 to the registrant's Form 10-Q filed with the Commission on August 14, 2008.
10.20	Management Services Agreement dated December 15, 2008 with Golden Grain Energy, LLC.	Exhibit 10.1 to the registrant's Form 10-K filed with the Commission on February 26, 2009.
10.21	Electrical Services Agreement dated March 6, 2009 with Hawkeye REC. +	Exhibit 10.1 to the registrant's Form 10-Q filed with the Commission on May 15, 2009.
10.22	U.S. Energy Agreement dated July 10, 2009.	Exhibit 10.1 to the registrant's Form 10-Q filed with the Commission on August 14, 2009.

51

10.23	Third Amendment to the Master Loan Agreement between Homeland Energy Solutions, LLC and Home Federal Savings Bank dated September 10, 2010.		Exhibit 10.1 to the registrant's Form 10-Q filed with the Commission on November 12, 2010.
10.24	Member Ethanol Fuel Marketing Agreement dated March 1, 2011 between Homeland Energy Solutions, LLC and RPMG, Inc. +		Exhibit 10.1 to the registrant's Form 10-Q filed with the Commission on May 16, 2011.
10.25	Corn Oil Marketing Agreement between RPMG, Inc. and Homeland Energy Solutions, LLC dated July 28, 2011. +		Exhibit 10.1 to the registrant's Form 10-Q filed with the Commission on August 12, 2011.
10.26	Third Amended Management Services Agreement between Homeland Energy Solutions, LLC and Golden Grain Energy, LLC dated December 15, 2011.		Exhibit 10.26 to the registrant's Form 10-K filed with the Commission on February 21, 2012.
10.27	Member Amended and Restated Marketing Agreement between RPMG, Inc. and Homeland Energy Solutions, LLC dated August 27, 2012. *+		Exhibit 10.1 to the registrant's Form 10-Q filed with the Commission on November 9, 2012.
10.28	Change in Control Agreement between David Finke and Homeland Energy Solutions, LLC dated January 1, 2013.		Exhibit 10.1 to the registrant's Form 10-Q filed with the Commission on May 15, 2013.
10.29	Change in Control Agreement between Stan Wubbena and Homeland Energy Solutions, LLC dated January 1, 2013.		Exhibit 10.2 to the registrant's Form 10-Q filed with the Commission on May 15, 2013.
10.30	Change in Control Agreement between Kevin Howes and Homeland Energy Solutions, LLC dated January 1, 2013.		Exhibit 10.3 to the registrant's Form 10-Q filed with the Commission on May 15, 2013.
10.31	Membership Unit Repurchase Agreement between Homeland Energy Solutions, LLC and Steven Retterath dated June 13, 2013.		Exhibit 10.1 to the registrant's Form 10-Q filed with the Commission on August 14, 2013.
10.32	Seventh Amendment to the Master Loan Agreement between Homeland Energy Solutions, LLC and Home Federal Savings Bank dated November 29, 2013.		Exhibit 10.32 to the registrant's Form 10-K filed with the Commission on February 27, 2014.
10.33	First Amendment to Second Supplement to Master Loan Agreement between Homeland Energy Solutions, LLC and Home Federal Savings Bank dated November 29, 2013.		Exhibit 10.33 to the registrant's Form 10-K filed with the Commission on February 27, 2014.
10.34	Eighth Amendment to the Master Loan Agreement between Homeland Energy Solutions, LLC and Home Federal Savings Bank dated February 24, 2014.		Exhibit 10.34 to the registrant's Form 10-K filed with the Commission on February 27, 2014.
10.35	Fourth Supplement to Master Loan Agreement between Homeland Energy Solutions, LLC and Home Federal Savings Bank dated February 24, 2014.		Exhibit 10.35 to the registrant's Form 10-K filed with the Commission on February 27, 2014.
10.36	$15 Million Term Note between Homeland Energy Solutions, LLC and Home Federal Savings Bank dated February 24, 2014.		Exhibit 10.36 to the registrant's Form 10-K filed with the Commission on February 27, 2014.
10.37	Termination Agreement between Golden Grain Energy, LLC and Homeland Energy Solutions, LLC dat4ed May 16, 2014		Exhibit 99.1 to the registrant's Form 8-K filed with the Commission on May 16, 2014
10.38	Independent Contractor Agreement between Walter Wendland and Homeland Energy Solutions, LLC dated May 12, 2014		Exhibit 10.1 to the registrant's Form 10-K filed with the Commission on August 12, 2014
14.1	Code of Ethics.		Exhibit 14.1 to the registrant's Form 10-K filed with the Commission on February 26, 2009.
31.1	Certificate Pursuant to 17 CFR 240.13a-14(a)	X

52

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
101	The following financial information from Homeland Energy Solutions, LLC's Annual Report on Form 10-K for the fiscal year ended December 31, 2014, formatted in XBRL (eXtensible Business Reporting Language): (i) Balance Sheets as of December 31, 2014 and 2013, (ii) Statements of Operations for the fiscal years ended December 31, 2014, 2013 and 2012, (iii) Statements of Cash Flows for the fiscal years ended December 31, 2014, 2013 and 2012, (iv) Statement of Changes in Members' Equity, and (v) the Notes to Financial Statements.**

________________________________

(+) Confidential Treatment Requested.

(**) Furnished herewith.

SIGNATURES

Pursuant to the requirements of Section 13 or 15(d) 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:	February 27, 2015	/s/ Patrick Boyle
		Patrick Boyle
		President and Chief Executive Officer (Principal Executive Officer)
Date:	February 27, 2015	/s/ David A. Finke
		David A. Finke
		Treasurer/Chief Financial Officer (Principal Financial Officer)

Pursuant to the requirements of the Securities Exchange Act of 1934, this report has been signed below by the following persons on behalf of the registrant and in the capacities and on the dates indicated.

53

Date:	February 27, 2015	/s/ Patrick Boyle
		Patrick Boyle, Chairman and Director
Date:	February 27, 2015	/s/ Mathew Driscoll
		Mathew Driscoll, Director
Date:	February 27, 2015	/s/ Keith Eastman
		Keith Eastman, Director
Date:	February 27, 2015	/s/ Stephen Eastman
		Stephen Eastman, Director
Date:	February 27, 2015	/s/ Leslie Hansen
		Leslie Hansen, Director
Date:	February 27, 2015	/s/ Edward Hatten
		Edward Hatten, Director
Date:	February 27, 2015	/s/ Maurice Hyde
		Maurice Hyde, Vice Chairman and Director
Date:	February 27, 2015	/s/ Chad Kuhlers
		Chad Kuhlers, Director
Date:	February 27, 2015	/s/ Christine Marchand
		Christine Marchand, Secretary and Director
Date:	February 27, 2015	/s/ Barney Retterath
		Barney Retterath, Director
Date:	February 27, 2015	/s/ Randy Bruess
		Randy Bruess, Director

54

EX-31.1

CERTIFICATIONS

I, Patrick Boyle, certify that:

1.    I have reviewed this annual report on Form 10-K of Homeland Energy Solutions, LLC;

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

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

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

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

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

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

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

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

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

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

Date:	February 27, 2015	/s/ Patrick Boyle
		Patrick Boyle, Chief Executive Officer

EX-31.2

CERTIFICATIONS

I, David A. Finke, certify that:

1.    I have reviewed this annual report on Form 10-K of Homeland Energy Solutions, LLC;

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

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

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

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

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

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

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

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

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

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

Date:	February 27, 2015	/s/ David A. Finke
		David A. Finke, Chief Financial Officer

EX-32.1

CERTIFICATION PURSUANT TO 18 U.S.C. SECTION 1350

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

In connection with this annual report on Form 10-K of Homeland Energy Solutions, LLC (the “Company”) for the fiscal year ended December 31, 2014, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Patrick Boyle, Chief Executive Officer of the Company, certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

1. The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934, as amended; and

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

Dated:	February 27, 2015	/s/ Patrick Boyle
		Patrick Boyle,
		Chief Executive Officer

EX-32.2

CERTIFICATION PURSUANT TO 18 U.S.C. SECTION 1350

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

In connection with this annual report on Form 10-K of Homeland Energy Solutions, LLC (the “Company”) for the fiscal year ended December 31, 2014, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, David A. Finke, Chief Financial Officer of the Company, certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

1. The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934, as amended; and

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

Dated:	February 27, 2015	/s/ David A. Finke
		David A. Finke,
		Chief Financial Officer

XML

Supply Commitments (Details) (Supply Commitment [Member])	12 Months Ended
	Dec. 31, 2014 gal
Ethanol [Member]
Supply Commitment [Line Items]
Supply Commitment, Minimum Amount at Varying Fixed Price, Gallons	14,000,000
Supply Commitment, Minimum Amount at Basis Price Levels, Gallons	21,000,000
Corn Oil [Member]
Supply Commitment [Line Items]
Supply Commitment, Remaining Minimum Amount Committed, Weight	2,000,000
Distillers Grains [Member]
Supply Commitment [Line Items]
Supply Commitment, Remaining Minimum Amount Committed, Weight	56,000

XML

Quarterly Financial Data (Unaudited) (Details) (USD $)	3 Months Ended												12 Months Ended
	Dec. 31, 2014	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2012	Sep. 30, 2012	Jun. 30, 2012	Mar. 31, 2012	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Quarterly Financial Data (Unaudited) [Abstract]
Revenue	$ 77,647,934	$ 83,212,628	$ 87,823,949	$ 81,752,306	$ 91,650,539	$ 98,342,436	$ 112,243,015	$ 97,975,795	$ 88,951,683	$ 84,499,206	$ 93,780,274	$ 92,011,614	$ 330,436,877	$ 400,211,785	$ 359,242,777
Gross Profit	13,865,303	20,393,602	23,036,031	15,439,851	14,068,250	5,614,185	8,613,215	3,157,969	684,733	(1,769,920)	1,896,219	2,367,009	72,756,188	31,453,619	3,178,041
Operating Income (Loss)	12,359,011	19,199,400	22,044,490	14,437,092	12,749,220	4,939,290	7,944,088	2,440,555	677	(2,416,309)	1,240,174	1,594,601	68,039,993	28,073,153	419,143
Net Income	$ 12,527,889	$ 19,247,197	$ 22,145,502	$ 14,695,363	$ 12,655,235	$ 5,062,318	$ 8,038,058	$ 2,478,297	$ 94,904	$ (2,467,293)	$ 1,221,495	$ 1,645,659	$ 68,615,951	$ 28,233,908	$ 494,765
Basic & diluted net income per capital unit	$ 193.98	$ 298.01	$ 342.89	$ 227.54	$ 195.95	$ 73.28	$ 88.87	$ 27.40	$ 1.05	$ (27.28)	$ 13.51	$ 18.20	$ 1,062.41	$ 359.48	$ 5.47

XML

Derivative Instruments - Income Statement (Details) (Not Designated as Hedging Instrument [Member], USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Instruments, Realized Gain (Loss) Recognized in Income	$ 4,415,000	$ 5,855,000
Derivative Instruments, Unrealized Gain (Loss) Recognized in Income	98,000	(720,000)
Derivative Instruments, Gain (Loss) Recognized in Income	4,513,000	5,135,000
Commodity Contract [Member] | Cost of Sales [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Instruments, Realized Gain (Loss) Recognized in Income	4,698,000	5,915,000	(5,152,000)
Derivative Instruments, Unrealized Gain (Loss) Recognized in Income	(185,000)	(437,000)	999,000
Derivative Instruments, Gain (Loss) Recognized in Income	4,513,000	5,478,000	(4,153,000)
Commodity Contract [Member] | Sales [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Instruments, Realized Gain (Loss) Recognized in Income	(283,000)	(60,000)
Derivative Instruments, Unrealized Gain (Loss) Recognized in Income	283,000	(283,000)
Derivative Instruments, Gain (Loss) Recognized in Income	$ 0	$ (343,000)

XML

Committed Shares to be Redeemed (Details) (USD $)	3 Months Ended	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2011
Nature of Business and Significant Accounting Policies [Abstract]
Stock Repurchased and Retired During Period, Shares			25,860	1,000
Commitment to redeem membership units	$ 30,000,000	$ 30,000,000	$ 30,000,000
Earnings Per Share, Basic and Diluted, Including Redeemed Shares	$ 138.51	$ 758.65
Director [Member]
Nature of Business and Significant Accounting Policies [Abstract]
Commitment to redeem membership units			$ 30,000,000

XML

Lease Obligations (Tables)

12 Months Ended

Dec. 31, 2014

Lease Obligations [Abstract]

Operating Leases Minimum Rental Commitments

2015	$	1,663,000
2016	1,663,000
2017	861,000
2018	156,000
Total lease commitments	$	4,343,000

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Purchase Commitments Other (Details) (Public Utilities, Inventory, Fuel [Member], USD $)	Dec. 31, 2014
Public Utilities, Inventory, Fuel [Member]
Long-term Purchase Commitment [Line Items]
Purchase Obligation, Due in 2015	$ 3,787,000
Purchase Obligation, Due in 2016	3,787,000
Purchase Obligation, Due in 2017	3,787,000
Purchase Obligation, Due in 2018	3,787,000
Purchase Obligation, Due in 2019	947,000
Purchase Obligation	$ 16,095,000

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Debt (Details) (Home Federal Savings Bank [Member], USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013
Term Loan [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount	$ 15,000,000
Debt Instrument, Interest Rate, Effective Percentage	3.26%
Debt Instrument, Periodic Payment	271,614
Long-term Debt	0
Line of Credit [Member] | Term Revolving Loan [Member]
Debt Instrument [Line Items]
Debt Instrument, Basis Spread on Variable Rate	3.10%
Line of Credit Facility, Maximum Borrowing Capacity	20,000,000
Line of Credit Facility, Interest Rate at Period End	3.258%
Line of Credit Facility, Amount Outstanding	$ 0	$ 15,000,000
Line of Credit [Member] | Term Loan [Member]
Debt Instrument [Line Items]
Debt Instrument, Basis Spread on Variable Rate	3.10%

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Fair Value Measurements (Details) (USD $)	Dec. 31, 2014	Dec. 31, 2013
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Trading securities	$ 32,220,801	$ 0
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Trading securities	32,221,000
Derivative Assets	292,000	251,000
Derivative Liabilities	(224,000)	(283,000)
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Trading securities	0
Derivative Assets	0	0
Derivative Liabilities	0	0
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Trading securities	0
Derivative Assets	0	0
Derivative Liabilities	0	0
Estimate of Fair Value Measurement [Member] | Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Trading securities	32,221,000
Derivative Assets	292,000	251,000
Derivative Liabilities	$ (224,000)	$ (283,000)

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Nature of Business and Significant Accounting Policies

12 Months Ended

Dec. 31, 2014

Nature of Business and Significant Accounting Policies [Abstract]

Nature of Business and Significant Accounting Policies

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. The Company has capacity to produce in excess of 135 million gallons annually and sells distillers dried grains and corn oil as byproducts of ethanol production.

Organization

Homeland Energy Solutions, LLC is organized as an Iowa limited liability company. The members' liability is limited as specified in Homeland Energy Solutions' operating agreement and pursuant to the Iowa Revised Uniform Limited Liability Company Act.

Significant Accounting Policies:

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.

Cash and Cash Equivalents

The Company maintains its accounts primarily at one financial institution. At various times, the Company's cash balances may exceed amounts insured by the Federal Deposit Insurance Corporation. The Company has not experienced losses in such accounts.

Trading Securities

Investments bought and held principally for the purpose of selling them in the the near term are classified as trading securities. Trading securities are measured at fair value using prices obtained from pricing services. Any unrealized or realized gains and losses on the trading securities are recorded as part of other income (expense).

At December 31, 2014, trading securities consisted of short term bond mutual funds with an approximate cost of $32,201,000 and fair value of $32,221,000. For the fiscal year ended December 31, 2014, the Company recorded a net unrealized gain of approximately $20,000 from these investments as part of other income (expense). There were no trading securities held as of December 31, 2013.

The Board of Directors voted to set aside up to $30 million in trading securities that will be used by the Company for the repurchase of 25,860 membership units held by Steve Retterath per the terms of an agreement with Mr. Retterath entered into on June 13, 2013 by the Company.

Receivables

Credit sales are made primarily to one customer and no collateral is required. The Company carries these accounts receivable at face amount with no allowance for doubtful accounts due to the historical collection rates on these accounts.

Investments

The Company has a less than 20% investment interest in Renewable Products Marketing Group, LLC. This investment is being accounted for under the equity method of accounting under which the Company's share of net income is recognized as income in the Company's income statement and added to the investment account. The investment balance is included in other assets and the income recognized as other income. The investment is evaluated for indications of impairment on a regular basis, a loss would be recognized when the fair value is determined to be less than the carrying value.

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.

Property and Equipment

The Company incurred site selection and plan development costs on the proposed site that were capitalized. Significant additions, betterments and costs to acquire land options are capitalized, while expenditures for maintenance and repairs are charged to operations when incurred. Property and equipment are stated at cost. The Company uses the straight-line method of computing depreciation over the estimated useful lives as follows.

	Estimated Useful Life in Years
	Minimum	Maximum
Land Improvements	20	40
Buildings	10	40
Equipment	7	40

Land improvements relate to two general categories: road infrastructure and general sitework. Road infrastructure relates to the excavating and paving of surface roads and the sitework includes such things as the well system and earthmoving. Buildings relate to three general categories: grain handling, process and administrative buildings. Equipment relates to three general categories: mechanical equipment, rail handling equipments and administrative and maintenance equipment. Mechanical equipment generally relates to equipment for handling inventories and the production of ethanol and related products, including such things as boilers, cooling towers, grain bins, centrifuges, conveyors, fermentation tanks, pumps and drying equipment. Rail handling equipments relates to railroad track. Administrative and maintenance equipment includes vehicles, computer systems, security equipments, testing devices and shop equipment.

The Company reviewed its usage, continued maintenance and productivity of its processing and production equipment, based on this review the Company reevaluated the useful lives of such equipment. As such, effective October 1, 2012 the Company increased the estimated useful lives on a significant portion of its processing and production equipment from 10 to 15 years. This change in estimate is accounted for on a prospective basis. This change resulted in a decrease in depreciation expense, an increase to operating income and an increase in net income of approximately $750,000, and an increase in income per unit of $8.29 for the Fourth Quarter 2012.

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 in 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. The Company has concluded that no impairment is 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.

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.

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 were amortized over the term of the loan and utility rights are amortized over 15 years or the anticipated useful life utilizing a method that materially approximates the straight-line method. 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.

At December 31, 2014, the Company anticipates the following amortization of Utility Rights for the twelve month periods ended December 31:

2015	$	136,000
2016	136,000
2017	136,000
2018	136,000
2019	136,000
Thereafter	580,000
Total amortization	$	1,260,000

Revenue and Cost 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. The 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. Rail car lease costs incurred by the Company in the sale and shipment of distiller grain products are included in the cost of goods sold.

Income Taxes

The Company was formed under sections of the federal and state income tax laws which provide that, in lieu of corporate income taxes, the members separately account for their share of the Company's items of income, deductions, losses and credits. As a result of this election, no income taxes have been recognized in the accompanying financial statements.

Management has evaluated the Company's tax positions under the Financial Accounting Standards Board issued guidance on accounting for uncertainty in income taxes and concluded that the Company had taken no uncertain tax positions that require adjustment to the financial statements to comply with the provisions of this guidance. Generally, the Company is no longer subject to income tax examinations by the U.S. federal, state or local authorities for the years before 2011.

Committed Shares to be Redeemed

On June 13, 2013, the Company entered into an agreement with Steve Retterath, the Company's largest member, to repurchase and retire all of the membership units owned by Mr. Retterath. The Company agreed to close on this repurchase on or before August 1, 2013. The Company agreed to repurchase and retire 25,860 membership units owned by Mr. Retterath in exchange for $30 million, to be paid in two equal installments payable at closing and on July 1, 2014. The transaction failed to close by the scheduled date due to objections by Mr. Retterath. Due to all conditions of the agreement being met prior to, or on, August 1, 2013, the Company believes that it has a binding agreement with Mr. Retterath; as such the commitment to repurchase and retire the membership units is reflected in the financial statements as if the transaction had closed on August 1, 2013.

Net Income 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 per unit are the same.

Prior to, or on, August 1, 2013, the Company believes it has a binding agreement with Steve Retterath to repurchase and retire all 25,860 membership units owned by Mr. Retterath. These membership units have thus been excluded in the determination of net income per unit as presented in the Statement of Operations. The Company is currently involved in litigation with Mr. Retterath. There is potential that Mr. Retterath will continue as a unit holder upon conclusion of the litigation and said membership units would not be redeemed under the repurchase agreement. If the units are not redeemed, basic and diluted net income per unit, including the 25,860 units, for the three and twelve months ended December 31, 2014 would be $138.51 and $758.65, respectively.

Environmental Liabilities

The Company's operations are subject to environmental laws and regulations adopted by various governmental authorities in the jurisdiction in which it operates. These laws require the Company to investigate and remediate the effects of the release or disposal of materials at its locations. Accordingly, the Company has adopted policies, practices and procedures in the areas of pollution control, occupational health and the production, handling, storage and use of hazardous materials to prevent material environmental or other damage, and to limit the financial liability which could result from such events. Environmental liabilities are recorded when the Company's liability is probable and the costs can be reasonably estimated. No expense or liability, including asset retirement obligations, for environmental liabilities has been recorded for the years ended December 31, 2014, 2013, or 2012.

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. For the twelve months ended December 31, 2014, ethanol sales averaged approximately 79% of total revenues, while approximately 18% of revenues were generated from the sale of distiller grains and 3% of revenues were generated from the sale of corn oil. For the twelve months ended December 31, 2014, corn costs averaged approximately 78% of cost of goods sold.

The Company's operating and financial performance is largely driven by the prices at which it sells 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, in general, for less than gasoline at the wholesale level. Excess ethanol supply in the market, in particular, puts downward pressure on the price of ethanol. The Company's largest cost of production is corn. The cost of corn is generally impacted by factors such as supply and demand, weather, and government policies and programs. The Company's risk management program is used to protect against the price volatility of these commodities.

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Lease Obligations (Details) (Railroad Transportation Equipment [Member], USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Railroad Transportation Equipment [Member]
Operating Leased Assets [Line Items]
Operating Leases, Rent Expense	$ 1,664,000	$ 1,665,000	$ 1,334,000
Operating Lease Payments Due 2015	1,663,000
Operating Lease Payments Due 2016	1,663,000
Operating Lease Payments Due 2017	861,000
Operating Lease Payments Due 2018	156,000
Total Operating Lease Payments Due	$ 4,343,000

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Nature of Business and Significant Accounting Policies (Details) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013
Product Information [Line Items]
Trading securities	$ 32,220,801	$ 0
Net Realized and Unrealized Gain (Loss) on Trading Securities	20,000
Commitment to redeem membership units	30,000,000	30,000,000
Partners' Capital Account, Units, Redeemed		25,860
Ethanol [Member]
Product Information [Line Items]
Annual Production Capacity, Minimum	100,000,000
Annual Production Capacity, Current	135,000,000
Fair Value, Measurements, Recurring [Member]
Product Information [Line Items]
Trading Securities, Cost	32,201,000
Estimate of Fair Value Measurement [Member] | Fair Value, Measurements, Recurring [Member]
Product Information [Line Items]
Trading securities	32,221,000
Director [Member]
Product Information [Line Items]
Commitment to redeem membership units		$ 30,000,000

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Quarterly Financial Data (Unaudited) (Tables)

12 Months Ended

Dec. 31, 2014

Quarterly Financial Data (Unaudited) [Abstract]

Schedule of Quarterly Financial Information

2014	First Quarter		Second Quarter		Third Quarter			Fourth Quarter
Total Revenues	$	81,752,306	$	87,823,949	$	83,212,628		$	77,647,934
Gross Profit	15,439,851		23,036,031		20,393,602			13,865,303
Operating Income	14,437,092		22,044,490		19,199,400			12,359,011
Net Income	14,695,363		22,145,502		19,247,197			12,527,889
Basic & diluted earnings per unit	$	227.54	$	342.89	$	298.01		$	193.98
2013	First Quarter		Second Quarter		Third Quarter			Fourth Quarter
Total Revenues	$	97,975,795	$	112,243,015	$	98,342,436		$	91,650,539
Gross Profit	3,157,969		8,613,215		5,614,185			14,068,250
Operating Income	2,440,555		7,944,088		4,939,290			12,749,220
Net Income	2,478,297		8,038,058		5,062,318			12,655,235
Basic & diluted earnings per unit	$	27.40	$	88.87	$	73.28		$	195.95
2012	First Quarter		Second Quarter		Third Quarter			Fourth Quarter
Total Revenues	$	92,011,614	$	93,780,274	$	84,499,206		$	88,951,683
Gross Profit (Loss)	2,367,009		1,896,219		(1,769,920		)	684,733
Operating Income (Loss)	1,594,601		1,240,174		(2,416,309		)	677
Net Income (Loss)	1,645,659		1,221,495		(2,467,293		)	94,904
Basic & diluted earnings (loss) per unit	$	18.20	$	13.51	$	(27.28	)	$	1.05

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Employee Benefit Plans (Details) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Employee Benefit Plans [Abstract]
Defined Benefit Plan, Contributions by Employer	$ 77,000	$ 64,000	$ 69,000

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Investment (Details)	Dec. 31, 2014
Nature of Business and Significant Accounting Policies [Abstract]
Equity Method Investment, Ownership Percentage	20.00%

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Property, Plant and Equipment (Details) (USD $)	12 Months Ended
	Dec. 31, 2014
Property, Plant and Equipment [Line Items]
Increase in Net Income During Period	$ 750,000
Income (Loss) from Continuing Operations, Per Basic Share	$ 8.29
Other Machinery and Equipment [Member] | Minimum [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Estimated Useful Lives	10
Other Machinery and Equipment [Member] | Maximum [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Estimated Useful Lives	15
Land Improvements [Member] | Minimum [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Estimated Useful Lives	20
Land Improvements [Member] | Maximum [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Estimated Useful Lives	40
Building [Member] | Minimum [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Estimated Useful Lives	10
Building [Member] | Maximum [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Estimated Useful Lives	40
Equipment [Member] | Minimum [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Estimated Useful Lives	7
Equipment [Member] | Maximum [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Estimated Useful Lives	40

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Statement of Members' Equity Parenthetical	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2011
Stock Repurchased and Retired During Period, Shares	25,860	1,000

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Amortization of Loan Fees and Utility Rights (Details) (USD $)	12 Months Ended
	Dec. 31, 2014
Deferred Costs, Capitalized, Prepaid, and Other Assets Disclosure [Abstract]
Amoritzation of financing costs and utility rights, future minimum payments, due in 2015	$ 136,000
Amoritzation of financing costs and utility rights, future minimum payments, due in 2016	136,000
Amoritzation of financing costs and utility rights, future minimum payments, due in 2017	136,000
Amoritzation of financing costs and utility rights, future minimum payments, due in 2018	136,000
Amoritzation of financing costs and utility rights, future minimum payments, due in 2019	136,000
Amoritzation of financing costs and utility rights, future minimum payments, due thereafter	580,000
Amortization of Financing Costs	$ 1,260,000

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Related Party (Details) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Investor [Member]
Related Party Transaction [Line Items]
Equity Method Investments	$ 2,646,000	$ 2,305,000
Ethanol [Member] | Investor [Member]
Related Party Transaction [Line Items]
Sales	262,029,000	305,444,000	276,321,000
Marketing Fees	141,000	225,000	392,000
Ethanol [Member] | RPMG [Member]
Related Party Transaction [Line Items]
Accounts Receivable	(1,495,000)	5,245,000	199,000
Distillers Grains [Member] | Unrelated Party [Member]
Related Party Transaction [Line Items]
Sales	59,715,000	82,552,000	71,272,000
Marketing Fees	722,000	744,000	723,000
Distillers Grains [Member] | CHS [Member]
Related Party Transaction [Line Items]
Accounts Receivable	595,000	2,147,000	2,077,000
Corn Oil [Member] | Investor [Member]
Related Party Transaction [Line Items]
Sales	8,976,000	12,558,000	11,649,000
Marketing Fees	$ 46,000	$ 67,000	$ 67,000

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Balance Sheets (USD $)	Dec. 31, 2014	Dec. 31, 2013
CURRENT ASSETS
Cash and cash equivalents	$ 32,522,840	$ 38,490,952
Trading securities	32,220,801	0
Accounts receivable	1,248,484	7,484,886
Derivative instruments	1,304,697	1,180,775
Inventory	9,517,127	7,397,733
Prepaid and other	1,978,443	1,901,710
Total current assets	78,792,392	56,456,056
PROPERTY AND EQUIPMENT
Land and improvements	22,539,771	22,533,935
Buildings	5,528,027	5,366,168
Equipment	140,904,830	139,453,228
Construction in progress	440,875	108,577
Gross Property and Equipment	169,413,503	167,461,908
Less accumulated depreciation	64,194,898	53,959,742
Total property and equipment	105,218,605	113,502,166
OTHER ASSETS
Loan fees, net of amortization of $1,249,653 and $1,145,047	0	27,925
Utility rights, net of amortization of $1,046,441 and $910,053	1,261,588	1,397,976
Other assets	3,234,488	2,694,003
Total Other Assets	4,496,076	4,119,904
TOTAL ASSETS	188,507,073	174,078,126
CURRENT LIABILITIES
Accounts payable	9,000,883	8,654,638
Commitment to redeem membership units	30,000,000	30,000,000
Interest payable	0	1,361
Property tax payable	483,036	464,524
Payroll payable	753,939	507,187
Total current liabilities	40,237,858	39,627,710
COMMITMENTS AND CONTINGENCIES
LONG-TERM LIABILITIES
Term revolving loan	0	15,000,000
Other Liabilities	419,904	303,526
Total long-term liabilities	419,904	15,303,526
MEMBERS' EQUITY, (64,585 and 64,585 units issued and outstanding as of December 31, 2014 and 2013, respectively	147,849,311	119,146,890
TOTAL LIABILITIES AND MEMBERS' EQUITY	$ 188,507,073	$ 174,078,126

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Derivative Instruments - Balance Sheet (Details) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013
Derivatives, Fair Value [Line Items]
Derivative instruments	1,304,697	$ 1,180,775
Corn [Member] | Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Derivative, Nonmonetary Notional Amount, Percent of Required Need, Coverage	9.00%
Minimum [Member] | Corn [Member] | Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Derivative, Nonmonetary Notional Amount, Percent of Required Need, Yearly Average	5.00%
Maximum [Member] | Corn [Member] | Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Derivative, Nonmonetary Notional Amount, Percent of Required Need, Yearly Average	60.00%
Other Current Assets [Member]
Derivatives, Fair Value [Line Items]
Other Receivables from Broker-Dealers and Clearing Organizations	1,237,000	1,213,000
Derivative instruments	1,305,000	1,181,000
Other Current Assets [Member] | Commodity Contract [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	292,000	251,000
Derivative Asset, Fair Value, Gross Liability	(224,000)	$ (283,000)
Corn [Member]
Derivatives, Fair Value [Line Items]
Concentration Risk, Amount of Material	46,000,000

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Statements of Cash Flows Parenthetical (USD $)	3 Months Ended	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2014	Dec. 31, 2012
Cash paid for interest, net of capitalized interest of none, none and none, respectively	$ 0	$ 0	$ 0

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Inventory (Details) (USD $)	Dec. 31, 2014	Dec. 31, 2013
Inventory [Abstract]
Raw Materials	$ 5,962,251	$ 4,617,404
Work in Process	1,402,369	1,600,041
Finished Goods	2,152,507	1,180,288
Inventory	$ 9,517,127	$ 7,397,733

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Nature of Business and Significant Accounting Policies (Tables)

12 Months Ended

Dec. 31, 2014

Nature of Business and Significant Accounting Policies [Abstract]

Property, Plant and Equipment

	Estimated Useful Life in Years
	Minimum	Maximum
Land Improvements	20	40
Buildings	10	40
Equipment	7	40

Amortization of Loan Fees and Utility Rights

2015	$	136,000
2016	136,000
2017	136,000
2018	136,000
2019	136,000
Thereafter	580,000
Total amortization	$	1,260,000

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Debt Nature of Business (Details) (Ethanol [Member])	12 Months Ended
	Dec. 31, 2014 gal
Ethanol [Member]
Product Information [Line Items]
Annual Production Capacity, Minimum	100,000,000

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Commitments, Contingencies and Agreements (Tables)

12 Months Ended

Dec. 31, 2014

Commitments, Contingencies and Agreements [Abstract]

Schedule of Related Party Transactions

	2014			2013		2012
Sales ethanol - RPMG	$	262,029,000		$	305,444,000	$	276,321,000
Sales distiller grains	59,715,000			82,552,000		71,272,000
Sales corn oil - RPMG	8,976,000			12,558,000		11,649,000
Marketing fees ethanol - RPMG	$	141,000		$	225,000	$	392,000
Marketing fees distiller grains	722,000			744,000		723,000
Marketing fees corn oil - RPMG	46,000			67,000		67,000
	2014			2013		2012
Amount due from/(to) RPMG	$	(1,495,000	)	$	5,245,000	$	199,000
Amount due from CHS	595,000			2,147,000		2,077,000

Contractual Obligation, Fiscal Year Maturity Schedule

2015	$	3,787,000
2016	3,787,000
2017	3,787,000
2018	3,787,000
2019	947,000
Total anticipated commitments	$	16,095,000

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Statement of Members' Equity (USD $)	Total	Stockholders' Equity, Total [Member]
Members' Equity at Dec. 31, 2010		$ 112,483,814
Stock Repurchased and Retired During Period, Value		(1,000,000)
Distribution to members		(7,145,155)
Net Income		36,353,768
Members' Equity at Dec. 31, 2011		140,692,427
Distribution to members	12,029,185	(12,029,185)
Net Income	494,765	494,765
Equity adjustment in investee	215,610	215,610
Members' Equity at Dec. 31, 2012		129,373,617
Distribution to members	8,460,635	(8,460,635)
Net Income	28,233,908	28,233,908
Equity adjustment in investee	0
Members' Equity at Dec. 31, 2013	119,146,890	119,146,890
Distribution to members	39,913,530	(39,913,530)
Net Income	68,615,951	68,615,951
Equity adjustment in investee	0
Commitment to redeem membership units		(30,000,000)
Members' Equity at Dec. 31, 2014	$ 147,849,311	$ 147,849,311

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Balance Sheets Parenthetical (USD $)	Dec. 31, 2014	Dec. 31, 2013
Other Assets:
Loan fees, net of amortization	$ 1,249,653	$ 1,145,047
Utility rights, net of amortization	$ 1,046,441	$ 910,053
MEMBERS’ EQUITY
Members Capital units issued and outstanding	64,585	64,585

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Fair Value Measurements

12 Months Ended

Dec. 31, 2014

Fair Value Measurements [Abstract]

Fair Value Measurements

FAIR VALUE MEASUREMENTS

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.

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:

Trading securities: Trading securities consisting of mutual funds, corporate bonds, and certificates of deposit are reported at fair value utilizing Level 1 inputs. Trading securities are measured at fair value using prices obtained from pricing services.

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 December 31, 2014 and December 31, 2013, 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
Trading Securities
December 31, 2014
Assets	$	32,221,000		$	32,221,000		$	—	$	—
Derivative financial instruments
December 31, 2014
Assets	$	292,000		$	292,000		$	—	$	—
Liabilities	(224,000		)	(224,000		)	—		—
December 31, 2013
Assets	$	251,000		$	251,000		$	—	$	—
Liabilities	(283,000		)	(283,000		)	—		—

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Document and Entity Information Document (USD $)	12 Months Ended
	Dec. 31, 2014	Feb. 27, 2015	Jun. 30, 2014
Document Information [Line Items]
Entity Registrant Name	HOMELAND ENERGY SOLUTIONS LLC
Entity Central Index Key	0001366744
Current Fiscal Year End Date	--12-31
Entity Filer Category	Non-accelerated Filer
Document Type	10-K
Document Period End Date	Dec. 31, 2014
Document Fiscal Year Focus	2014
Document Fiscal Period Focus	FY
Amendment Flag	false
Entity Common Stock, Shares Outstanding		64,585
Entity Well-known Seasoned Issuer	No
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Public Float			$ 0

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Ligitagion Matters (Notes)

12 Months Ended

Dec. 31, 2014

Unit Redemption & Related Litigation [Abstract]

Unit Redemption and Related Litigation

LITIGATION MATTERS

Retterath

In relation to the repurchase agreement discussed in Note 4, on August 1, 2013 Mr. Retterath filed a lawsuit against the Company along with several directors, the Company's former CEO, CFO, Plant Manager, a former director and the Company's outside legal counsel in Florida state court. Mr. Retterath's factual basis for his claims is unclear from the complaint and amended complaints Mr. Retterath has filed, however, it appears that Mr. Retterath is claiming that certain actions taken by the Company violated fiduciary duties owed to him as a member or fraudulently induced him to take certain actions. Mr. Retterath is also claiming violations of state and federal securities laws and violations of Florida's deceptive and unfair trade practices statutes. On August 14, 2013, the Company filed a lawsuit in Iowa state court to enforce the repurchase agreement the Company entered into with Mr. Retterath.

GS Cleantech Corporation

On August 9, 2013, GS Cleantech Corporation (GS Cleantech), a subsidiary of Greenshift Corporation, filed a complaint against the Company alleging that the Company's operation of a corn oil extraction process licensed by the Company infringes patent rights claimed by GS Cleantech. GS Cleantech seeks royalties, damages and potentially triple damages associated with the alleged infringement, as well as attorney's fees from the Company. The Company filed a motion for summary judgment which was granted by the Court. The Company expects GS Cleantech will appeal this decision. The Company has filed an answer and counterclaims claiming invalidity of the patents, noninfringement, and inequitable conduct. The Company is not currently able to predict the outcome of the litigation with any degree of certainty.

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Statements of Operations (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Revenue	$ 330,436,877	$ 400,211,785	$ 359,242,777
Costs of Goods Sold	257,680,689	368,758,166	356,064,736
Gross Profit	72,756,188	31,453,619	3,178,041
Selling, general and administrative expenses	4,716,195	3,380,466	2,758,898
Operating Income	68,039,993	28,073,153	419,143
OTHER INCOME (EXPENSE)
Interest expense	(129,480)	(60,230)	(246,272)
Interest income	23,460	11,506	820
Other Income	681,978	209,479	321,074
Total Other Income (Expense)	575,958	160,755	75,622
Net Income	$ 68,615,951	$ 28,233,908	$ 494,765
Basic & diluted net income per capital unit	$ 1,062.41	$ 359.48	$ 5.47
Distribution per capital unit	$ 618.00	$ 131.00	$ 133.00
Weighted average number of units outstanding for the calculation of basic & diluted net income per capital unit	64,585	78,542	90,445

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Related Party Transactions

12 Months Ended

Dec. 31, 2014

Related Party Transactions [Abstract]

Related Party Transactions

RELATED PARTY TRANSACTIONS

Due to Former Member

On June 13, 2013, the Company entered into an agreement with Steve Retterath, the Company's largest member, to repurchase and retire all of the units owned by Mr. Retterath. The Company agreed to close on this repurchase on or before August 1, 2013. The Company agreed to repurchase and retire 25,860 memberships units owned by Mr. Retterath in exchange for $30 million, to be paid in two equal installments payable at closing and on July 1, 2014. The transaction failed to close by the scheduled date due to objections by Mr. Retterath. The Company believes that it has a binding agreement with Mr. Retterath. On August 14, 2013, the Company filed a lawsuit against Mr. Retterath in Iowa state court to enforce the terms of the repurchase agreements. The Company is asking the Iowa court to require Mr. Retterath to complete the repurchase agreement pursuant to its terms.

Mr. Retterath contends that he is not bound by the agreement. The Company's position is as of the closing date, Mr. Retterath is no longer the equitable owner of any membership units in the Company. As a result, the Company has recorded a $30 million short-term liability related to the amount the Company agreed to pay Mr. Retterath to repurchase his membership units and has correspondingly reduced members' equity on its balance sheet. If the Company is ultimately unsuccessful in its lawsuit against Mr. Retterath, the Company will reevaluate the accounting considerations made during the period of time that the lawsuit is pending.

Other Matters

The Company purchases corn and materials from members of its Board of Directors who own or manage elevators or are local producers of corn. Purchases during the years ended December 31, 2014, 2013 and 2012 from these companies and individuals totaled approximately $4,187,000, $4,347,000 and $0, respectively. Amounts due to those members was $0 as of December 31, 2014 and 2013.

Previously, the Company had an agreement with Golden Grain Energy, LLC (Golden Grain), a member of the Company, for management services. Pursuant to the agreement, Homeland Energy and Golden Grain 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. This agreement was terminated on May 16, 2014. For the years ended December 31, 2014, 2013, and 2012 the Company incurred net costs of approximately $47,000, $139,000 and $119,000, respectively related to this agreement.

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Debt

12 Months Ended

Dec. 31, 2014

Debt [Abstract]

Debt

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 Company currently has a term revolving loan with Home Federal.

Term Revolving Loan

Under the terms of the Seventh Amendment to the Master Loan Agreement, the Company has a $20 million term revolving loan which has a maturity date of August 1, 2018. Interest on the term revolving loan accrues at a rate equal to the one month LIBOR plus 310 basis points, 3.26% on December 31, 2014. The Company is required to make monthly payments of interest until the maturity date of the term revolving loan on August 1, 2018, on which date the unpaid principal balance of the term revolving loan becomes due. The balance outstanding on the term revolving loan as of December 31, 2014 and December 31, 2013 was $0 and $15,000,000 respectively.

2014 Term Loan

Under the terms of the Fourth Supplement to the Master Loan Agreement, dated February 28, 2014, the Company had a $15 million term loan which had a maturity date of March 1, 2019. Interest on the term loan accrued at a rate equal to the one month LIBOR plus 310 basis points, 3.26% on December 31, 2014. The Company was required to make equal monthly payments of principal and accrued interest in an amount equal to $271,614 per month, or such greater or lesser amount determined by the lender to fully amortize the principal balance of the term loan over the period of five years. The 2014 term loan was paid in full by the Company on June 18, 2014 and the outstanding principal balance on the term loan as of December 31, 2014 was $0.

Covenants

In addition, during the term of the Loans, the Company is subject to certain financial covenants at various times calculated monthly, quarterly or annually, including restriction of the payment of dividends and capital expenditures and maintenance of certain financial ratios including the minimum working capital, tangible net worth, and a fixed charge ratio as defined by the Master Loan Agreement. 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.

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Inventory (Tables)

12 Months Ended

Dec. 31, 2014

Inventory [Abstract]

Schedule of Inventory

Inventory consisted of the following as of December 31, 2014 and 2013.

	December 31, 2014		December 31, 2013
Raw Materials	$	5,962,251	$	4,617,404
Work in Process	1,402,369		1,600,041
Finished Goods	2,152,507		1,180,288
Totals	$	9,517,127	$	7,397,733

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Quarterly Financial Data (Unaudited)

12 Months Ended

Dec. 31, 2014

Quarterly Financial Data (Unaudited) [Abstract]

Quarterly Financial Data (Unaudited)

QUARTERLY FINANCIAL DATA (UNAUDITED)

Summary quarterly results for the years ended December 31, 2014, 2013 and 2012 are as follows:

2014	First Quarter		Second Quarter		Third Quarter			Fourth Quarter
Total Revenues	$	81,752,306	$	87,823,949	$	83,212,628		$	77,647,934
Gross Profit	15,439,851		23,036,031		20,393,602			13,865,303
Operating Income	14,437,092		22,044,490		19,199,400			12,359,011
Net Income	14,695,363		22,145,502		19,247,197			12,527,889
Basic & diluted earnings per unit	$	227.54	$	342.89	$	298.01		$	193.98
2013	First Quarter		Second Quarter		Third Quarter			Fourth Quarter
Total Revenues	$	97,975,795	$	112,243,015	$	98,342,436		$	91,650,539
Gross Profit	3,157,969		8,613,215		5,614,185			14,068,250
Operating Income	2,440,555		7,944,088		4,939,290			12,749,220
Net Income	2,478,297		8,038,058		5,062,318			12,655,235
Basic & diluted earnings per unit	$	27.40	$	88.87	$	73.28		$	195.95
2012	First Quarter		Second Quarter		Third Quarter			Fourth Quarter
Total Revenues	$	92,011,614	$	93,780,274	$	84,499,206		$	88,951,683
Gross Profit (Loss)	2,367,009		1,896,219		(1,769,920		)	684,733
Operating Income (Loss)	1,594,601		1,240,174		(2,416,309		)	677
Net Income (Loss)	1,645,659		1,221,495		(2,467,293		)	94,904
Basic & diluted earnings (loss) per unit	$	18.20	$	13.51	$	(27.28	)	$	1.05

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Employee Benefit Plans

12 Months Ended

Dec. 31, 2014

Employee Benefit Plans [Abstract]

Employee Benefit Plans

EMPLOYEE BENEFIT PLANS

The Company has adopted a Simple IRA Adoption Agreement which provides retirement savings options for all eligible employees. Employees meeting certain eligibility requirements can participate in the plan. The Company makes a matching contribution based on the participants' eligible wages. For the years ended December 31, 2014, 2013 and 2012 the Company made matching contributions of approximately $77,000, $64,000 and $69,000, respectively.

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Commitments, Contingencies and Agreements

12 Months Ended

Dec. 31, 2014

Commitments, Contingencies and Agreements [Abstract]

Commitments and Contingencies and Agreements

COMMITMENTS, CONTINGENCIES AND AGREEMENTS

Ethanol, corn oil, and distiller grains marketing agreements and major customers

The Company has entered into a marketing agreement with RPMG, a related party, to sell all ethanol produced at the plant to an entity in which the Company invests in at a mutually agreed on price, less commission and transportation charges. As of December 31, 2014, the Company had commitments to sell approximately 14,000,000 gallons at various fixed prices and 21,000,000 gallons at basis price levels indexed against exchanges for delivery through March 31, 2015.

The Company has entered into a marketing agreement with RPMG to sell all corn oil produced at the plant at a mutually agreed on price, less marketing fees and transportation charges. As of December 31, 2014, the Company had commitments to sell approximately 2,000,000 pounds at various fixed and basis price levels indexed against exchanges for delivery through January 31, 2015.

The Company also has an investment in RPMG, LLC, included in other assets, totaling approximately $2,646,000 and $2,305,000 as of December 31, 2014 and 2013.

The Company has entered into a marketing agreement to sell all distiller grains produced at the plant to CHS, 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, 2014. The agreement calls for automatic renewal for successive one-year terms unless 90-day prior written notice is given before the current term expires. As of December 31, 2014, the Company had approximately 56,000 tons of distiller grains commitments for delivery through June 2015 at various fixed prices.

Sales and marketing fees related to the agreements in place for the years ended December 31, 2014, 2013 and 2012 were as follows:

	2014			2013		2012
Sales ethanol - RPMG	$	262,029,000		$	305,444,000	$	276,321,000
Sales distiller grains	59,715,000			82,552,000		71,272,000
Sales corn oil - RPMG	8,976,000			12,558,000		11,649,000
Marketing fees ethanol - RPMG	$	141,000		$	225,000	$	392,000
Marketing fees distiller grains	722,000			744,000		723,000
Marketing fees corn oil - RPMG	46,000			67,000		67,000
	2014			2013		2012
Amount due from/(to) RPMG	$	(1,495,000	)	$	5,245,000	$	199,000
Amount due from CHS	595,000			2,147,000		2,077,000

At December 31, 2014, the Company had approximately $16,371,000 in outstanding corn purchase commitments for bushels at various prices and approximately 2,464,000 bushels of unpriced corn through March 2016 accounted for under the normal purchase exclusion.

The Company has commitments for minimum purchases of various utilities such as natural gas and electricity over the next 5 years, accounted for under the normal purchase exclusion, which are anticipated to approximate the following for the twelve month periods ending December 31:

2015	$	3,787,000
2016	3,787,000
2017	3,787,000
2018	3,787,000
2019	947,000
Total anticipated commitments	$	16,095,000

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Lease Obligations

12 Months Ended

Dec. 31, 2014

Lease Obligations [Abstract]

Lease Obligations

LEASE OBLIGATIONS

The Company leases rail cars and rail moving 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 years ended December 31, 2014, 2013 and 2012 was approximately $1,664,000, $1,665,000 and $1,334,000.

At December 31, 2014, the Company had the following approximate minimum rental commitments under non-cancelable operating leases for the twelve month periods ended December 31:

2015	$	1,663,000
2016	1,663,000
2017	861,000
2018	156,000
Total lease commitments	$	4,343,000

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Derivative Instruments

12 Months Ended

Dec. 31, 2014

Derivative Instruments [Abstract]

Derivative Instruments

    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 the 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 46 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 December 31, 2014, the Company has hedged portions of its anticipated monthly purchases for corn averaging approximately 9% 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, as amended and, therefore, are not marked to market in the Company's financial statements. The following table represents the approximate amount of realized and unrealized gains (losses) and changes in fair value recognized in earnings on commodity contracts for periods ended December 31, 2014, 2013, and 2012 and the fair value of derivatives as of December 31, 2014 and 2013:

	Income Statement Classification	Realized Gain (Loss)			Change In Unrealized Gain (Loss)			Total Gain (Loss)
Derivatives not designated as hedging instruments: Commodity contracts for the year ended December 31, 2014.
	Cost of Goods Sold	$	4,698,000		$	(185,000	)	$	4,513,000
	Revenue	(283,000		)	283,000			—
	Total	$	4,415,000		$	98,000		$	4,513,000
Derivatives not designated as hedging instruments: Commodity contracts for the year ended December 31, 2013.
	Cost of Goods Sold	$	5,915,000		$	(437,000	)	$	5,478,000
	Revenue	(60,000		)	(283,000		)	(343,000		)
	Total	$	5,855,000		$	(720,000	)	$	5,135,000
Derivatives not designated as hedging instruments: Commodity contracts for the year ended December 31, 2012.
	Cost of Goods Sold	$	(5,152,000	)	$	999,000		$	(4,153,000	)

	Balance Sheet Classification	December 31, 2014			December 31, 2013
Futures and option contracts through December 2015
In gain position		$	292,000		$	251,000
In loss position		(224,000		)	(283,000		)
Cash held by broker		1,237,000			1,213,000
	Current Asset	$	1,305,000		$	1,181,000

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Risk and Uncertainties (Details)	12 Months Ended
	Dec. 31, 2014
Sales Revenue, Segment [Member] | Ethanol [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage	79.00%
Sales Revenue, Segment [Member] | Distillers Grains [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage	18.00%
Sales Revenue, Segment [Member] | Corn Oil [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage	3.00%
Cost of Goods, Segment [Member] | Corn [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage	78.00%

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Accounting Policies

12 Months Ended

Dec. 31, 2014

Nature of Business and Significant Accounting Policies [Abstract]

Accounting Estimates

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.

Cash and Cash Equivalents

Cash and Cash Equivalents

The Company maintains its accounts primarily at one financial institution. At various times, the Company's cash balances may exceed amounts insured by the Federal Deposit Insurance Corporation. The Company has not experienced losses in such accounts.

Trading Securities

Trading Securities

Investments bought and held principally for the purpose of selling them in the the near term are classified as trading securities. Trading securities are measured at fair value using prices obtained from pricing services. Any unrealized or realized gains and losses on the trading securities are recorded as part of other income (expense).

At December 31, 2014, trading securities consisted of short term bond mutual funds with an approximate cost of $32,201,000 and fair value of $32,221,000. For the fiscal year ended December 31, 2014, the Company recorded a net unrealized gain of approximately $20,000 from these investments as part of other income (expense). There were no trading securities held as of December 31, 2013.

The Board of Directors voted to set aside up to $30 million in trading securities that will be used by the Company for the repurchase of 25,860 membership units held by Steve Retterath per the terms of an agreement with Mr. Retterath entered into on June 13, 2013 by the Company.

Receivables

Receivables

Credit sales are made primarily to one customer and no collateral is required. The Company carries these accounts receivable at face amount with no allowance for doubtful accounts due to the historical collection rates on these accounts.

Investments

Investments

The Company has a less than 20% investment interest in Renewable Products Marketing Group, LLC. This investment is being accounted for under the equity method of accounting under which the Company's share of net income is recognized as income in the Company's income statement and added to the investment account. The investment balance is included in other assets and the income recognized as other income. The investment is evaluated for indications of impairment on a regular basis, a loss would be recognized when the fair value is determined to be less than the carrying value.

Inventories

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.

Property and Equipment

Property and Equipment

The Company incurred site selection and plan development costs on the proposed site that were capitalized. Significant additions, betterments and costs to acquire land options are capitalized, while expenditures for maintenance and repairs are charged to operations when incurred. Property and equipment are stated at cost. The Company uses the straight-line method of computing depreciation over the estimated useful lives as follows.

	Estimated Useful Life in Years
	Minimum	Maximum
Land Improvements	20	40
Buildings	10	40
Equipment	7	40

Land improvements relate to two general categories: road infrastructure and general sitework. Road infrastructure relates to the excavating and paving of surface roads and the sitework includes such things as the well system and earthmoving. Buildings relate to three general categories: grain handling, process and administrative buildings. Equipment relates to three general categories: mechanical equipment, rail handling equipments and administrative and maintenance equipment. Mechanical equipment generally relates to equipment for handling inventories and the production of ethanol and related products, including such things as boilers, cooling towers, grain bins, centrifuges, conveyors, fermentation tanks, pumps and drying equipment. Rail handling equipments relates to railroad track. Administrative and maintenance equipment includes vehicles, computer systems, security equipments, testing devices and shop equipment.

The Company reviewed its usage, continued maintenance and productivity of its processing and production equipment, based on this review the Company reevaluated the useful lives of such equipment. As such, effective October 1, 2012 the Company increased the estimated useful lives on a significant portion of its processing and production equipment from 10 to 15 years. This change in estimate is accounted for on a prospective basis. This change resulted in a decrease in depreciation expense, an increase to operating income and an increase in net income of approximately $750,000, and an increase in income per unit of $8.29 for the Fourth Quarter 2012.

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 in 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. The Company has concluded that no impairment is necessary.

Derivative Instruments

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.

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.

Loan Fees and Utility Rights

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 were amortized over the term of the loan and utility rights are amortized over 15 years or the anticipated useful life utilizing a method that materially approximates the straight-line method. 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.

At December 31, 2014, the Company anticipates the following amortization of Utility Rights for the twelve month periods ended December 31:

2015	$	136,000
2016	136,000
2017	136,000
2018	136,000
2019	136,000
Thereafter	580,000
Total amortization	$	1,260,000

Revenue Recognition

Revenue and Cost 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. The 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. Rail car lease costs incurred by the Company in the sale and shipment of distiller grain products are included in the cost of goods sold.

Income Taxes

Income Taxes

The Company was formed under sections of the federal and state income tax laws which provide that, in lieu of corporate income taxes, the members separately account for their share of the Company's items of income, deductions, losses and credits. As a result of this election, no income taxes have been recognized in the accompanying financial statements.

Management has evaluated the Company's tax positions under the Financial Accounting Standards Board issued guidance on accounting for uncertainty in income taxes and concluded that the Company had taken no uncertain tax positions that require adjustment to the financial statements to comply with the provisions of this guidance. Generally, the Company is no longer subject to income tax examinations by the U.S. federal, state or local authorities for the years before 2011

Committed Shares to be Redeemed

Committed Shares to be Redeemed

On June 13, 2013, the Company entered into an agreement with Steve Retterath, the Company's largest member, to repurchase and retire all of the membership units owned by Mr. Retterath. The Company agreed to close on this repurchase on or before August 1, 2013. The Company agreed to repurchase and retire 25,860 membership units owned by Mr. Retterath in exchange for $30 million, to be paid in two equal installments payable at closing and on July 1, 2014. The transaction failed to close by the scheduled date due to objections by Mr. Retterath. Due to all conditions of the agreement being met prior to, or on, August 1, 2013, the Company believes that it has a binding agreement with Mr. Retterath; as such the commitment to repurchase and retire the membership units is reflected in the financial statements as if the transaction had closed on August 1, 2013.

Net Income per Unit

Net Income 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 per unit are the same.

Prior to, or on, August 1, 2013, the Company believes it has a binding agreement with Steve Retterath to repurchase and retire all 25,860 membership units owned by Mr. Retterath. These membership units have thus been excluded in the determination of net income per unit as presented in the Statement of Operations. The Company is currently involved in litigation with Mr. Retterath. There is potential that Mr. Retterath will continue as a unit holder upon conclusion of the litigation and said membership units would not be redeemed under the repurchase agreement. If the units are not redeemed, basic and diluted net income per unit, including the 25,860 units, for the three and twelve months ended December 31, 2014 would be $138.51 and $758.65, respectively.

Environmental Liabilities

Environmental Liabilities

The Company's operations are subject to environmental laws and regulations adopted by various governmental authorities in the jurisdiction in which it operates. These laws require the Company to investigate and remediate the effects of the release or disposal of materials at its locations. Accordingly, the Company has adopted policies, practices and procedures in the areas of pollution control, occupational health and the production, handling, storage and use of hazardous materials to prevent material environmental or other damage, and to limit the financial liability which could result from such events. Environmental liabilities are recorded when the Company's liability is probable and the costs can be reasonably estimated. No expense or liability, including asset retirement obligations, for environmental liabilities has been recorded for the years ended December 31, 2014, 2013, or 2012.

Risks and Uncertainties

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. For the twelve months ended December 31, 2014, ethanol sales averaged approximately 79% of total revenues, while approximately 18% of revenues were generated from the sale of distiller grains and 3% of revenues were generated from the sale of corn oil. For the twelve months ended December 31, 2014, corn costs averaged approximately 78% of cost of goods sold.

The Company's operating and financial performance is largely driven by the prices at which it sells 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, in general, for less than gasoline at the wholesale level. Excess ethanol supply in the market, in particular, puts downward pressure on the price of ethanol. The Company's largest cost of production is corn. The cost of corn is generally impacted by factors such as supply and demand, weather, and government policies and programs. The Company's risk management program is used to protect against the price volatility of these commodities.

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Derivative Instruments (Tables)

12 Months Ended

Dec. 31, 2014

Derivative Instruments [Abstract]

Schedule of Other Derivatives Not Designated as Hedging Instruments, Income Statement Classification

	Income Statement Classification	Realized Gain (Loss)			Change In Unrealized Gain (Loss)			Total Gain (Loss)
Derivatives not designated as hedging instruments: Commodity contracts for the year ended December 31, 2014.
	Cost of Goods Sold	$	4,698,000		$	(185,000	)	$	4,513,000
	Revenue	(283,000		)	283,000			—
	Total	$	4,415,000		$	98,000		$	4,513,000
Derivatives not designated as hedging instruments: Commodity contracts for the year ended December 31, 2013.
	Cost of Goods Sold	$	5,915,000		$	(437,000	)	$	5,478,000
	Revenue	(60,000		)	(283,000		)	(343,000		)
	Total	$	5,855,000		$	(720,000	)	$	5,135,000
Derivatives not designated as hedging instruments: Commodity contracts for the year ended December 31, 2012.
	Cost of Goods Sold	$	(5,152,000	)	$	999,000		$	(4,153,000	)

Schedule of Fair Value of Derivatives Instruments, Balance Sheet

	Balance Sheet Classification	December 31, 2014			December 31, 2013
Futures and option contracts through December 2015
In gain position		$	292,000		$	251,000
In loss position		(224,000		)	(283,000		)
Cash held by broker		1,237,000			1,213,000
	Current Asset	$	1,305,000		$	1,181,000

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Subsequent Events (Details) (USD $)	12 Months Ended			3 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Mar. 31, 2015
Subsequent Event [Line Items]
Distribution per capital unit	$ 618.00	$ 131.00	$ 133.00
Distribution to members	$ 39,913,530	$ 8,460,635	$ 12,029,185
Members Capital units issued and outstanding	64,585	64,585
Cash Distribution [Member]
Subsequent Event [Line Items]
Distribution per capital unit				$ 152.00
Distribution to members				$ 9,816,920
Members Capital units issued and outstanding				64,585

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Purchase Commitments (Details) (Corn [Member], USD $)	12 Months Ended
	Dec. 31, 2014 bu
Corn [Member]
Long-term Purchase Commitment [Line Items]
Long-term Purchase Commitment, Amount	$ 16,371,000
Long-term Purchase Commitment, Minimum Mass Required	2,464,000

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Statements of Cash Flows (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
CASH FLOWS FROM OPERATING ACTIVITIES
Net Income	$ 68,615,951	$ 28,233,908	$ 494,765
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	10,476,150	10,445,877	11,817,100
Unrealized loss (gain) on risk management activities	(123,922)	160,506	259,437
Change in working capital components:
Inventory	(2,119,394)	2,257,999	845,702
Prepaid expenses and other	(76,733)	36,256	309,158
Accounts receivable	6,236,402	(5,099,248)	1,010,396
Accounts payable and other accrued expenses	726,526	(1,756,304)	1,860,217
Net cash provided by operating activities	83,734,980	34,278,994	16,596,775
CASH FLOWS FROM INVESTING ACTIVITIES
Purchase of trading securities	(32,220,801)	0	0
Payments for equipment and construction in progress	(1,968,649)	(2,399,329)	(1,437,370)
Proceeds from sale of equipment	17,054	0	0
Increase in other assets	(540,485)	(1,009,857)	(593,348)
Decrease in restricted cash	0	0	174,687
Net cash (used in) investing activities	(34,712,881)	(3,409,186)	(1,856,031)
CASH FLOWS FROM FINANCING ACTIVITIES
Distribution to members	(39,913,530)	(8,460,635)	(12,029,185)
Payments for debt issuance costs	(76,681)	0	0
Proceeds from long-term borrowings	30,000,000	130,350,000	24,750,000
Payments on long-term borrowings	(45,000,000)	(116,350,000)	(30,533,333)
Net cash provided by (used in) financing activities	(54,990,211)	5,539,365	(17,812,518)
Net increase (decrease) in cash	(5,968,112)	36,409,173	(3,071,774)
Cash and Cash Equivalents - Beginning	38,490,952	2,081,779	5,153,553
Cash and Cash Equivalents - Ending	32,522,840	38,490,952	2,081,779
SUPPLEMENTAL DISCLOSURES OF CASH FLOW INFORMATION
Cash paid for interest, net of capitalized interest of none, none, and none, respectively	130,841	61,381	256,727
SUPPLEMENTAL SCHEDULE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Equity adjustment in investee	0	0	215,610
Accounts payable related to property and equipment	0	213,989	0
Director [Member]
SUPPLEMENTAL SCHEDULE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Commitment to redeem membership units	$ 0	$ 30,000,000

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Inventory

12 Months Ended

Dec. 31, 2014

Inventory [Abstract]

Inventory

INVENTORY

Inventory consisted of the following as of December 31, 2014 and 2013.

	December 31, 2014		December 31, 2013
Raw Materials	$	5,962,251	$	4,617,404
Work in Process	1,402,369		1,600,041
Finished Goods	2,152,507		1,180,288
Totals	$	9,517,127	$	7,397,733

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Fair Value Measurements (Tables)

12 Months Ended

Dec. 31, 2014

Fair Value Measurements [Abstract]

Schedule of Fair Value, Assets and Liabilities Measured on Recurring Basis

	Total			Level 1			Level 2		Level 3
Trading Securities
December 31, 2014
Assets	$	32,221,000		$	32,221,000		$	—	$	—
Derivative financial instruments
December 31, 2014
Assets	$	292,000		$	292,000		$	—	$	—
Liabilities	(224,000		)	(224,000		)	—		—
December 31, 2013
Assets	$	251,000		$	251,000		$	—	$	—
Liabilities	(283,000		)	(283,000		)	—		—

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Related Party Transactions (Details) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2011	Dec. 31, 2014	Dec. 31, 2012
Related Party Transaction [Line Items]
Stock Repurchased and Retired During Period, Shares	25,860	1,000
Due to Related Parties	$ 30,000,000		$ 30,000,000
Director [Member]
Related Party Transaction [Line Items]
Purchases from Related Party	4,347,000		4,187,000	0
Commitment to redeem membership units	30,000,000		0
Due to Related Parties	30,000,000
Investor [Member]
Related Party Transaction [Line Items]
Management Services Agreement Fees with Related Party	$ 139,000		$ 47,000	$ 119,000

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Subsequent Events (Notes)

12 Months Ended

Dec. 31, 2014

Subsequent Events [Abstract]

Subsequent Events

SUBSEQUENT EVENTS

On February 17, 2015, the Company's board of directors declared a cash distribution of $9,816,920 to be paid to 64,585 membership units which equals $152 per membership unit. The record date for the distribution was February 17, 2015. The Company anticipates paying this distribution in March 2015. No distribution will be paid by the Company to Steve Retterath.