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 October 31, 2013
	OR
o	Transition report pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934.
	For the transition period from               to               .
	COMMISSION FILE NUMBER 000-51277

GRANITE FALLS ENERGY, LLC

(Exact name of registrant as specified in its charter)

Minnesota	41-1997390
(State or other jurisdiction of incorporation or organization)	(I.R.S. Employer Identification No.)
15045 Highway 23 SE, Granite Falls, MN 56241-0216
(Address of principal executive offices)
(320) 564-3100
(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

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

x Yes     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 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

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).

o Yes     x No

The aggregate market value of the membership units held by non-affiliates of the registrant was $21,185,000 as of April 30, 2013. The membership units are not listed on an exchange or otherwise publicly traded. Additionally, the membership units are subject to significant restrictions on transfer under the registrant's operating and member control agreement. The value of the membership units for this purpose has been based solely upon the initial offering price of the membership units. In determining this value, the registrant has assumed that all of its governors, chief executive officer, chief financial officer and beneficial owners of 5% or more of its outstanding membership units are affiliates, but this assumption shall not apply to or be conclusive for any other purpose.

As of January 29, 2014, there were 30,606 membership units outstanding.

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 (October 31, 2013). This proxy statement is referred to in this report as the 2014 Proxy Statement.

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INDEX

	Page Number
PART I	3
Item 1. Business	4
Item 1A. Risk Factors	10
Item 1B. Unresolved Staff Comments	12
Item 2. Properties	13
Item 3. Legal Proceedings	13
Item 4. Mine Safety Disclosures	13
PART II	13
Item 5. Market for Registrant's Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities	13
Item 6. Selected Financial Data	15
Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations	17
Item 7A. Quantitative and Qualitative Disclosures About Market Risk	31
Item 8. Financial Statements and Supplementary Data	33
Item 9. Changes in and Disagreements with Accountants on Accounting and Financial Disclosure	56
Item 9A. Controls and Procedures	56
Item 9B. Other Information	57
PART III	58
Item 10. Directors, Executive Officers and Corporate Governance	58
Item 11. Executive Compensation	58
Item 12. Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters	58
Item 13. Certain Relationships and Related Transactions, and Director Independence	58
Item 14. Principal Accountant Fees and Services	58
PART IV	59
Item 15. Exhibits, Financial Statement Schedules	59
SIGNATURES	60

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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 of corn and natural gas;

• Demand for corn exceeding supply; and corresponding corn price increases;

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

• Our ability to profitably operate the ethanol plant and maintain a positive spread between the selling price of our products and our raw materials costs;

• Results of our hedging transactions and other risk management strategies;

• Decreases in the market prices of ethanol and distillers grains;

• Ethanol supply exceeding demand; and corresponding ethanol price reductions;

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

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

• The performance of Heron Lake BioEnergy, LLC, an ethanol production company in which we indirectly own approximately 60.8% of the outstanding membership units;

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

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

• Changes in federal and/or state laws or regulations, including the elimination or modification of the federal renewable fuels standard;

• Changes and advances in ethanol production technology;

• Effects of mergers, consolidations or contractions in the ethanol industry;

• Competition from alternative fuel additives;

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

• Our inelastic demand for corn, as it is the only available feedstock for our plant;

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

• The imposition of tariffs or other duties on ethanol imported into Europe;

• The performance of our modified water intake system; and

• Volatile commodity and financial markets.

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 persons acting on our behalf. We do not undertake any duty to update forward-looking statements after the date they are made or to conform forward-looking statements to actual results or to changes in circumstances or expectations. 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 at our website at www.granitefallsenergy.com, under “SEC Compliance,” which includes links to reports we have filed with the Securities and Exchange Commission, including annual, quarterly and current reports. The contents of our website are not incorporated by reference in this Annual Report on Form 10-K. The Securities and Exchange Commission also maintains an Internet site (http://www.sec.gov) through which the public can access our reports.

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ITEM 1.BUSINESS

Business Development

Granite Falls Energy, LLC (“Granite Falls Energy” or the “Company”) is a Minnesota limited liability company formed on December 29, 2000. We are currently producing fuel-grade ethanol, distillers grains and crude corn oil for sale. Our plant has an approximate annual production capacity of 60 million gallons of denatured ethanol, but is currently permitted to produce up to 70 million gallons of undenatured ethanol on a twelve month rolling sum basis. We intend to continue working toward increasing production to take advantage of the additional production allowed pursuant to our permit as long as we believe it is profitable to do so.

Our operating results are largely driven by the prices at which we sell our ethanol, distillers grains, and corn oil as well as the costs related to the production of these products. The price of ethanol has historically fluctuated with the price of petroleum-based products such as unleaded gasoline, heating oil and crude oil. The price of distillers grains has historically been influenced by the price of corn as a substitute livestock feed. We expect these price relationships to continue for the foreseeable future. Our largest costs of production are corn, natural gas, depreciation and manufacturing chemicals. Our cost of corn is largely impacted by geopolitical supply and demand factors and the outcome of our risk management strategies. Prices for natural gas, manufacturing chemicals and denaturant are tied directly to the overall energy sector, crude oil and unleaded gasoline.

On July 31, 2013, we acquired a majority interest in Heron Lake BioEnergy, LLC ("Heron Lake" or "HLBE"), a Minnesota limited liability company. Heron Lake owns an ICM/Fagen designed plant that started production in September 2007. Heron Lake produces fuel-grade ethanol, distillers grains and crude corn oil for sale. HLBE's plant has an approximate annual production capacity of 55 million gallons, but is currently permitted to produce up to 59.2 million gallons per year.

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 we produce are ethanol, distillers grains and corn oil.

Ethanol

Ethanol is ethyl alcohol, a fuel component made primarily from corn and various other grains, which can be 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. The principal purchasers of ethanol are generally wholesale gasoline marketers or blenders. The principal markets for our ethanol are petroleum terminals in the continental United States.

Approximately 77.2% of our consolidated revenue, net of derivative activity, was derived from the sale of ethanol during our fiscal year ended October 31, 2013. Ethanol sales accounted for approximately 79.1% and 83.0% of our consolidated revenue, net of derivative activity, for the fiscal years ended October 31, 2012 and 2011, respectively.

Distillers Grains

A principal co-product of the ethanol production process is distillers grains, a high protein, high-energy animal feed supplement primarily marketed to the dairy, swine, poultry and beef industries. Distillers grains contain by-pass protein that is superior to other protein supplements such as cottonseed meal and soybean meal. By-pass proteins are more digestible to the animal, thus generating greater lactation in milk cows and greater weight gain in beef cattle and swine. Distillers grains can also be included in the rations of breeder hens and laying hens which can potentially contain up to 20% and 15% percent distillers grains, respectively.

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Approximately 19.7% of our consolidated revenue was derived from the sale of distillers grains during our fiscal year ended October 31, 2013. Distillers grains sales accounted for approximately 18.4% and 14.5% of our consolidated revenue for the fiscal years ended October 31, 2012 and 2011, respectively.

Corn Oil

Corn oil is used primarily as a biodiesel feedstock and as a supplement for animal feed. Corn oil sales accounted for approximately 2.9% of our consolidated revenue during our fiscal year ended October 31, 2013 and 2.5% for our fiscal years ended October 31, 2012 and 2011.

Principal Product Markets

As described below in “Distribution of Principal Products”, we market and distribute all of our ethanol and all of our distillers grains shipped by rail through professional third party marketers. Our ethanol and distillers grains marketers make all decisions with regard to where our products are marketed. Our ethanol and distillers grains are primarily sold in the domestic market. As distillers grains become more accepted as an animal feed substitute throughout the world, distillers grains exporting may increase.

We expect our ethanol and distillers grains marketers to explore all markets for our products, including export markets. However, due to high transportation costs, and the fact that we are not located near a major international shipping port, we expect our products to continue to be marketed primarily domestically.

Distribution of Principal Products

Our ethanol plant is located near Granite Falls, Minnesota in Chippewa County. We selected the Granite Falls site because of its accessibility to road and rail transportation and its proximity to grain supplies. It is served by the TC&W Railway which provides connection to the Canadian Pacific and Burlington Northern Santa Fe Railroads. The completion of our rail loop during our 2012 fiscal year enables us to load unit trains. Our site is in close proximity to major highways that connect to major population centers such as Minneapolis, Minnesota; Chicago, Illinois; and Detroit, Michigan.

The ethanol plant owned by HLBE is located near Heron Lake, Minnesota. That plant is served by the Union Pacific Railroad.

Ethanol Distribution

Eco-Energy, Inc. (“Eco-Energy”) is our ethanol marketer for both the Granite Falls plant and the HLBE plant. Pursuant to the agreements we have with Eco-Energy, it has agreed to market the entire ethanol output of our ethanol plants and to arrange for the transportation of ethanol. We pay Eco-Energy a certain percentage of the FOB plant price in consideration of Eco-Energy's services.

Distillers Grains Distribution

Since February 1, 2011, Renewable Products Marketing Group, LLC (“RPMG”) has served as the distillers' grains marketer for our Granite Falls plant. Pursuant to this agreement, RPMG markets all the distillers grains produced at our Granite Falls plant.

Gavilon Ingredients, LLC serves as the distillers' grains marketer for HLBE pursuant to an off-take agreement that became effective as of November 1, 2013. Under this agreement, Gavilon Ingredients, LLC purchases all of the distillers' grains produced at our Heron Lake ethanol plant in exchange for a service fee.

Corn Oil Distribution

RPMG is also our corn oil marketer for both the Granite Falls plant and the HLBE plant. Currently, RPMG markets our corn oil, which is used primarily as a biodiesel feedstock and as a supplement for animal feed. Our corn oil is transported by truck to end users located primarily in the upper Midwest. We pay RPMG a commission based on each pound of corn oil sold by RPMG under the agreement.

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New Products and Services

We did not introduce any new products or services during our fiscal year ended October 31, 2013.

Sources and Availability of Raw Materials

Corn Supply

To produce approximately 60 million gallons of undenatured ethanol per year our Granite Falls ethanol plant needs approximately 21.5 million bushels of corn per year, or approximately 60,000 bushels per day, as the feedstock for its dry milling process. The grain supply for our Granite Falls plant is obtained from Farmers Cooperative Elevator Company ("FCE"), our exclusive grain procurement agent. Our members are not obligated to deliver corn to our Granite Falls plant. We will be forced to seek alternative corn suppliers if FCE cannot meet our needs. The term of our agreement with FCE expires in November 2017.

The HLBE ethanol plant requires approximately 18 million bushels of corn per year. HLBE generally does not have long-term, fixed price contracts for the purchase of corn and its members are not obligated to deliver corn to HLBE. Typically, HLBE purchases its corn directly from grain elevators, farmers, and local dealers within approximately 80 miles of Heron Lake, Minnesota.

Drought conditions in the United States in 2012 negatively impacted corn yields and resulted in increased corn prices. However, in 2013, despite delayed corn planting throughout much of the corn belt, a record corn crop was harvested. This crop has led to decreased prices and abundant supplies of corn. Management does not currently anticipate difficulty in securing the necessary quantities of corn needed for our plants to operate at capacity during our 2014 fiscal year.

We can attempt to mitigate fluctuations in the corn and ethanol markets by locking in a favorable margin through the use of hedging activities, including forward contracts. However, we are not always presented with an opportunity to lock in a favorable margin and our plant's profitability may be negatively impacted during periods of high grain prices.

Utilities

Natural Gas. Natural gas is a significant input to our manufacturing process.  We use natural gas to dry our distillers grains product to moisture contents at which it can be stored for long periods and transported greater distances. Our dried distillers grains can then be marketed to broader livestock markets, including poultry and swine markets in the continental United States, and can be shipped to international markets.

At our Granite Falls plant, we pay Center Point Energy/Minnegasco a per unit fee to move the natural gas through the pipeline and have guaranteed to move a minimum of 1,400,000 mmBTU annually through December 31, 2015, which is the ending date of the agreement. We also have an agreement with U.S. Energy Services, Inc. On our behalf, U.S. Energy Services procures contracts with various natural gas vendors to supply the natural gas necessary to operate the plant. We determined that sourcing our natural gas from a variety of vendors is more cost-efficient than using an exclusive supplier.

At the HLBE plant, we have a facilities agreement with Northern Border Pipeline Company which allows us access to an existing interstate natural gas pipeline located approximately 16 miles north from the plant. Agrinatural Gas, LLC ("Agrinatural Gas"), owned by our subsidiary, HLBE Pipeline Company, LLC, and Rural Energy Solutions, was formed to own and operate the pipeline and transports gas to HLBE pursuant to a transportation agreement. HLBE Pipeline Company, LLC owns 73% of Agrinatural Gas. HLBE also has a base agreement for the sale and purchase of natural gas with Constellation NewEnergy—Gas Division, LLC ("Constellation"). HLBE buys all of its natural gas from Constellation and this agreement runs for a three year period from November 1, 2011 to October 31, 2014.

Electricity. Our plants require a continuous supply of electricity. We have agreements in place to supply electricity to our plants.

Water. Our plants also require a continuous supply of water. In October 2013, we finished upgrading the water intake structure for our Granite Falls plant to an adjustable gravity-flow intake system that has been fully operational since November 5, 2013. This followed the removal of a dam located downstream from our previous water intake structure.

HLBE obtains its water pursuant to an industrial water supply agreement with the City of Heron Lake and Jackson County, Minnesota.

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Patents, Trademarks, Licenses, Franchises and Concessions

We do not currently hold any patents, trademarks, franchises or concessions. We were granted a license by 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, Inc. to design and build our ethanol plant.

Seasonality of Ethanol Sales

We experience some seasonality of demand for our ethanol. Since ethanol is predominantly blended with conventional 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. In addition, we experience some increased ethanol demand during holiday seasons related to increased gasoline demand.

Working Capital

We primarily use our working capital for purchases of raw materials necessary to operate the ethanol plants. Granite Falls Energy has a line of credit with United FCS, PCA. CoBank serves as administrative agent for this facility. The line of credit allows the Company to borrow, repay, and reborrow up to $6,000,000 subject to a borrowing base calculation and outstanding letters of credit. The line of credit and another credit facility provided by United FCS are secured by substantially all of our assets. Amounts borrowed under the revolving line of credit bear interest at one of three interest rate options selected by us, (i) at a variable weekly rate equal to 2.65% above the rate quoted by the British Bankers Association for the offering of one-month U.S. Dollar deposits, (ii) at a fixed rate to be quoted by CoBank, or (iii) at a fixed rate for up to 12 months equal to LIBOR plus 2.65%. Interest on amounts borrowed is payable monthly in arrears. As of October 31, 2013, the Company had no outstanding balance on this line of credit.

As of October 31, 2013, the Company had letters of credit totaling approximately $340,000, which reduced the amount available under this facility to $5,660,000.

HLBE has a revolving term note with AgStar Financial Services, PCA ("AgStar") used for working capital purposes. The revolving term note allows HLBE to borrow up to $18.5 million subject to letters of credit outstanding. All of HLBE's assets and real property are subject to security interests and mortgages in favor of AgStar as security for the obligations of the master loan agreement, including the revolving term note. Amounts outstanding on the term revolving loan bear interest at a variable rate equal to the greater of a LIBOR rate plus 3.50% or 5.0%, payable monthly. At October 31, 2013, the revolving term loan carried an interest rate of 5.0%. HLBE also pays an unused commitment fee on the unused portion of the term revolving term loan commitment at the rate of 0.35% per annum, payable in arrears in quarterly installments during the term of the revolving term loan. At October 31, 2013, HLBE had $6.0 million outstanding under the revolving term loan, which does not include a debt premium of approximately $280,000, and an additional $12.5 million was available. The amount available under the revolving term loan is reduced by $2.0 million at October 31 each year until September 2016, when the unpaid balance is due.

Dependence on One or a Few Major Customers

As discussed above, we have exclusive ethanol marketing agreements with Eco-Energy. Additionally, we have agreements with RPMG to market all of the distillers grains and corn oil produced at the Granite Falls plant; and agreements with Gavilon and RPMG to market all of the distillers grains and corn oil, respectively, produced at the Heron Lake plant. We rely on Eco-Energy, RPMG and Gavilon for the sale and distribution of all of our products. Therefore, we are highly dependent on Eco-Energy, RPMG and Gavilon for the successful marketing of our products. Any loss of these companies as our marketing agents for our ethanol, distillers grains, or corn oil could have a negative impact on our revenues.

Competition

We are in direct competition with numerous ethanol producers, many of whom 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 advantages of economies of scale due to their larger size and increased bargaining power with both customers and raw material suppliers. Following the significant growth in the ethanol industry during 2005 and 2006, the ethanol industry has grown at a much slower pace. As of January 6, 2014, the Renewable Fuels Association ("RFA") estimates that there are 211 ethanol production facilities in the United States with capacity to produce approximately 14.8 billion gallons of ethanol and another 6 plants under expansion or construction with capacity to produce an additional 165 million gallons per year. However, the RFA estimates that approximately 8% of the ethanol production capacity in the United States was not operating as of January 6, 2014. The largest ethanol producers include

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Archer Daniels Midland, POET, Valero Renewable Fuels, and Green Plains Renewable Energy, 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.

U.S. FUEL ETHANOL PRODUCTION CAPACITY BY TOP PRODUCERS

Producers of Approximately 1,000 million gallons per year (mmgy) or more

Company	Nameplate Capacity (mmgy)
Archer Daniels Midland	1,720.0
POET Biorefining	1,629.0
Valero Renewable Fuels	1,130.0
Green Plains Renewable Energy	1,004.0

Updated: January 6, 2014, Renewable Fuels Association

Ethanol is a commodity product where competition in the industry is predominantly based on price. Larger ethanol producers may be able to realize economies of scale in their operations that we are unable to realize. This could put us at a competitive disadvantage to other ethanol producers.

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. Several companies and researchers have commenced pilot projects to study the feasibility of commercially producing cellulosic ethanol and some companies have started constructing commercial scale plants. 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. Like ethanol, the emerging fuel cell industry offers a technological option to address worldwide energy costs, the long-term availability of petroleum reserves and environmental concerns. Fuel cells have emerged as a potential alternative to certain existing power sources because of their higher efficiency, reduced noise and lower emissions. If the fuel cell industry continues to expand and gain broad acceptance and becomes 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, which would negatively impact our profitability.

Process Improvement

We are continually working to develop new methods of operating the ethanol plants more efficiently. We continue to conduct process improvement activities in order to realize these efficiency improvements.

Governmental Regulation and Federal Ethanol Supports

Federal Ethanol Supports

The primary 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 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 RFS requirement for corn-based ethanol, such as the ethanol we produce, is capped at 15 billion gallons starting in 2015. For 2013, the RFS for corn-based ethanol was approximately 13.8 billion

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gallons, and the RFS for 2014 for corn-based ethanol was expected to be 14.4 billion gallons. However, the EPA has proposed a significant reduction to the RFS, resulting in an RFS for 2014 of 13.01 billion gallons. Current domestic ethanol production capacity may meet or exceed the current RFS for corn-based ethanol. If the EPA's proposal becomes a final rule, or if the RFS were to be otherwise reduced or eliminated by the exercise of the EPA's waiver authority or by Congress, the demand for ethanol may be negatively impacted.

Many in the ethanol industry believe that it will be difficult 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. 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 possibility of additional ethanol used in higher percentage blends such as E85 used in flex fuel vehicles. The RFS requires that 36 billion gallons of renewable fuels must be used each year by 2022, which equates to approximately 27% renewable fuels used per gallon of gasoline sold. In order to meet the RFS mandate and expand demand for ethanol, management believes higher percentage blends of ethanol must be utilized in standard vehicles.

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. Although many positive steps have been taken at the federal level to bring E15 to market, several states have a regulatory framework that may prevent sales of E15 in the short term. Additionally, sales of E15 may be limited because (i) it is not approved for use in all vehicles, (ii) the EPA requires a label that management believes may discourage consumers from using E15, and (iii) 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. This may prevent E15 from being used during certain times of the year in various states. As a result, management believes that E15 may not have an immediate impact on ethanol demand in the United States.

Historically, the ethanol industry benefited from the Volumetric Ethanol Excise Tax Credit (“VEETC”), which provided gasoline blenders with a volumetric ethanol excise tax credit of 45 cents per gallon of ethanol blended with gasoline. However, VEETC expired as of December 31, 2011. Due to the RFS, we anticipate that in the longer term the demand for ethanol will continue to mirror the RFS requirement. If the RFS is reduced or eliminated, demand for ethanol may be further reduced.

United States ethanol production was also formerly benefited by a 54 cent per gallon tariff imposed on ethanol imported into the United States. The 54 cent per gallon tariff expired December 31, 2011. In response, ethanol imports into the United States have generally increased. These imports increase supply in the United States, which in turn puts downward pressure on ethanol prices.

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, expand and operate the plants. 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 plants may increase. Any of these regulatory factors may result in higher costs or other adverse conditions effecting our operations, cash flows and financial performance.

We currently have obtained all of the necessary permits to operate the plants at their respective permitted rates. In the fiscal year ended October 31, 2013, we incurred costs and expenses of approximately $164,280 complying with environmental laws, including the cost of pursuing permit amendments. 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.

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Employees

As of the date of this report, we have 75 full time employees at our two consolidated ethanol plants. Seventeen of these employees are involved primarily in management and administration. The remaining employees are involved primarily in plant operations. We do not currently anticipate any significant change in the number of employees at our plant.

Financial Information about Geographic Areas

All of our operations are domiciled in the United States. All of the products sold to our customers for fiscal years 2013, 2012 and 2011 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 who decide where our products are marketed and we have no control over the marketing decisions made by our third-party professional marketers. These third-party marketers may decide to sell our products in countries other than the United States. However, we anticipate that our products will primarily be 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

Increases in the price of corn or natural gas would reduce our profitability.Our primary source of revenue is from the sale of ethanol, distillers grains and corn oil. Our results of operations and financial condition are significantly affected by the cost and supply of corn and natural gas. Changes in the price and supply of corn and natural gas are subject to and determined by market forces over which we have no control, including weather and general economic factors.

Ethanol production requires substantial amounts of corn. Generally, higher corn prices will produce lower profit margins and, therefore, negatively affect our financial performance. If a period of high corn prices were to be sustained for some time, such pricing may reduce our ability to operate profitably because of the higher cost of operating our plant. We may not be able to offset any increase in the price of corn by increasing the price of our products. If we cannot offset increases in the price of corn, our financial performance may be negatively affected.

The prices for and availability of natural gas are subject to volatile market conditions.  These market conditions often are affected by factors beyond our control such as higher prices as a result of colder than average weather conditions or natural disasters, overall economic conditions and foreign and domestic governmental regulations and relations.  Significant disruptions in the supply of natural gas could impair our ability to manufacture ethanol and more significantly, dried distillers grains for our customers.  Furthermore, increases in natural gas prices or changes in our natural gas costs relative to natural gas costs paid by competitors may adversely affect our results of operations and financial condition. We seek to minimize the risks from fluctuations in the prices of corn and natural gas through the use of hedging instruments.  However, these hedging transactions also involve risks to our business.  If we were to experience relatively higher corn and natural gas costs compared to the selling prices of our products for an extended period of time, the value of our units may be reduced.

Declines in the price of ethanol or distillers grains would significantly reduce our revenues. The sales prices of ethanol and distillers grains can be volatile as a result of a number of factors such as overall supply and demand, the price of gasoline and corn prices, levels of government support, and the availability and price of competing products. We are dependent on a favorable spread between the price we receive for our ethanol and distillers grains and the price we pay for corn and natural gas. Any lowering of ethanol and distillers grains prices, especially if it is associated with increases in corn and natural gas prices, may affect our ability to operate profitably. We anticipate the price of ethanol and distillers grains to continue to be volatile in our 2014 fiscal year. Declines in the prices we receive for our ethanol and distillers grains will lead to decreased revenues and may result in our inability to operate the ethanol plant profitably for an extended period of time which could decrease the value of our units.

The prices of ethanol and distillers grains may decline as a result of trade barriers imposed by foreign countries with respect to ethanol and distillers grains originating in the United Sates.An increasing amount of our industry's products are being exported. If producers and exporters of ethanol and distillers grains are subjected to trade barriers when selling products to foreign customers there may be a reduction in the price of these products in the United States. Declines in the price we receive for our products will lead to decreased revenues and may result in our inability to operate the ethanol plant profitably.

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We engage in hedging transactions which involve risks that could 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, natural gas and ethanol through the use of hedging instruments.  The effectiveness of our hedging strategies is dependent on the price of corn, natural gas and ethanol 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 fluctuation which may leave us vulnerable to high corn and natural gas prices, as well as low ethanol prices.

Our business is not diversified.  Our success depends largely on our ability to profitably operate our ethanol plants. 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 and distillers grains.  If economic or political factors adversely affect the market for ethanol and distillers grains, 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.

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 plants. We may not be able to replace these individuals should they decide to cease their employment with us, or if they become unavailable for any other reason. Any loss of these officers and key employees may prevent us from operating the ethanol plant profitably and could decrease the value of our units.

Risks Related to Ethanol Industry

Decreasing gasoline prices may negatively impact the selling price of ethanol which could reduce our ability to operate profitably. The price of ethanol tends to change partially in relation to the price of gasoline. Decreases in the price of ethanol reduce our revenue. Our profitability depends on a favorable spread between our corn and natural gas costs and the price we receive for our ethanol. If gasoline prices fall and ethanol prices follow during times when corn and/or natural gas prices are high, we may not be able to operate our ethanol plant profitably.

We operate in an intensely competitive industry and compete with larger, better financed entities 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 outside of the United States. The largest ethanol producers include Archer Daniels Midland, POET, Valero Renewable Fuels, and Green Plains Renewable Energy, each of which are each capable of producing significantly more ethanol than we produce. Further, many believe that there will be further consolidation in the ethanol industry in the future, which will likely lead to a few companies who control a significant portion of the ethanol production market. We may not be able to compete with these larger entities. 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. 

Competition from the advancement of alternative fuels may lessen the demand forethanol.  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 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 isexpensive, adds to air pollution, harms engines and/or takes more energy toproduce than it contributes may affect the 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. 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 conventional automobiles. 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.

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Sustained negative operating margins may require some ethanol producers to temporarily limit or cease production. Our ability and the ability of other ethanol producers to operate profitably is largely determined by the spread between the price paid for corn and the price received for ethanol. If this spread is narrow or is negative for a sustained period, some ethanol producers may elect to temporarily limit or cease production until their possibility for profitability returns. Although we currently have no plans to limit or cease ethanol production, we may be required to do so if we experience a period of sustained negative operating margins. In such an event, we would still incur certain fixed costs, which would impact our financial performance.

Risks Related to Regulation and Governmental Action

Because federal and state regulation heavily influence the supply of and demand for ethanol, changes in government regulation that adversely affect demand or supply will have a material adverse effect on our business. Various federal and state laws, regulations and programs impact the supply of and demand for ethanol. Some government regulation, for example those that provide economic incentives to ethanol producers, stimulate supply of ethanol by encouraging production and the increased capacity of ethanol plants. Others, such as a federal excise tax incentive program that provides gasoline distributors who blended ethanol with gasoline to receive a federal excise tax rate reduction for each blended gallon they sell, stimulate demand for ethanol by making it price competitive with other oxygenates. Further, tariffs generally apply to the import of ethanol from certain other countries, where the cost of production can be significantly less than in the U.S. These tariffs are designed to increase the cost of imported ethanol to a level more comparable to the cost of domestic ethanol by offsetting the benefit of the federal excise tax program. Tariffs have the effect of maintaining demand for domestic ethanol.

Additionally, the Environmental Protection Agency has established a revised annual renewable fuel standard (RFS2) that sets minimum national volume standards for use of renewable fuels. The RFS2 also sets volume standards for specific categories of renewable fuels: cellulosic, biomass-based diesel and total advanced renewable fuels. While our ethanol does not qualify as one of the new volume categories of renewable fuels, we believe that the overall renewable fuels requirement of RFS2 creates an incentive for the use of ethanol. Other federal and state programs that require or provide incentives for the use of ethanol create demand for ethanol. Government regulation and government programs that create demand for ethanol may also indirectly create supply for ethanol as additional producers expand or new companies enter the ethanol industry to capitalize on demand. In the case of the RFS2, while it creates a demand for ethanol, the existence of specific categories of renewable fuels also creates a demand for these types of renewable fuels and will likely provide an incentive for companies to further develop these products to capitalize on that demand. In these circumstances, the RFS2 may also reduce demand for ethanol in favor of the renewable fuels for which specific categories exist.

There have been proposals in Congress to reduce or eliminate RFS2. Additionally, in November 2013 the Environmental Protection Agency issued a proposed rule that would reduce the RFS2 levels for 2014 from the statutory volume requirement of 18.15 billion gallons to 15.21 billion gallons, and reduce the renewable volume obligations that can be satisfied by corn-based ethanol from 14.4 billion gallons to 13 billion gallons, which is less than the 2013 volume requirement of 13.8 billion gallons. If the Environmental Protection Agency's proposal becomes a final rule, or if RFS2 were to be otherwise reduced or eliminated by the exercise of the Environmental Protection Agency's waiver authority or by Congress, the demand for ethanol may be negatively impacted.

Changes in environmental regulations or violations of the regulations could beexpensive and reduce our profitability.  We are subject to extensive air, water supply, water discharge and other environmental laws and regulations.  In addition, some of these laws require our plant to operate under a number of environmental permits which must be renewed from time to time. These laws, regulations and permits can often require expensive pollution control equipment or operation 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, permit non-renewals, capital expenditures 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.

ITEM 1B.UNRESOLVED STAFF COMMENTS

This Item is not applicable to Granite Falls Energy because Granite Falls Energy is not an accelerated filer, a large accelerated filer or a well-known seasoned issuer, as those terms are defined in the rules of the Securities and Exchange Commission.

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ITEM 2. PROPERTIES.

Our Granite Falls ethanol plant is located approximately three miles east of Granite Falls, Minnesota in Chippewa County at the junction of Highways 212 and 23. The plant's address is 15045 Highway 23 SE, Granite Falls, Minnesota. The ethanol plant sits on approximately 216 acres. This site includes an administrative building which serves as our headquarters. The site also includes corn, ethanol, and distilers' grains handling facilities. All of our tangible and intangible property, real and personal, serves as the collateral for our credit facilities with United FCS, PCA.

HLBE's ethanol plant is sited on approximately 216 acres of land located near Heron Lake, Minnesota. The site includes corn, coal, ethanol, and distillers' grains storage and handling facilities. Located on these 216 acres is an approximately 7,320 square foot building that serves as HLBE's headquarters. The plant's address is 91246 390th Avenue, Heron Lake, Minnesota 56137-3175. All of HLBE's real property is subject to mortgages in favor of AgStar as security for loan obligations.

Our credit facilities are discussed in more detail under "MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS - Indebtedness".

ITEM 3.    LEGAL PROCEEDINGS

From time to time in the ordinary course of business, Granite Falls Energy, LLC or its subsidiaries may be named as a defendant in legal proceedings related to various issues, including workers' compensation claims, tort claims, or contractual disputes. We are not currently involved in any material legal proceedings.

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.

There is no public trading market for our units.

However, we have established through FNC Ag Stock Trade, LLC, a Unit Trading Bulletin Board, a private online matching service, in order to facilitate trading among our members.  The Unit Trading Bulletin Board has been designed to comply with federal tax laws and IRS regulations establishing a “qualified matching service,” as well as state and federal securities laws.  Our Unit Trading Bulletin Board consists of an electronic bulletin board that provides a list of interested buyers with a list of interested sellers, along with their non-firm price quotes.  The Unit Trading Bulletin Board does not automatically affect matches between potential sellers and buyers and it is the sole responsibility of sellers and buyers to contact each other to make a determination as to whether an agreement to transfer units may be reached.  We do not become involved in any purchase or sale negotiations arising from our Unit Trading Bulletin Board and have no role in effecting the transactions beyond approval, as required under our operating and member control 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 qualified matching service, we do not characterize Granite Falls Energy 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 securities laws, including any applicable registration requirements.

There are detailed timelines that must be followed under the Unit Trading Bulletin Board Rules and Procedures with respect to offers and sales of membership units.  All transactions must comply with the Unit Trading Bulletin Board Rules, our operating and member control agreement, and are subject to approval by our board of governors. 

As of October 31, 2013, there were approximately 951 holders of record of our membership units.

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The following table contains historical information by fiscal quarter for the past two fiscal years regarding the actual unit transactions that were completed by our unit-holders during the periods specified. We believe this most accurately represents the current trading value of the Company's units. The information was compiled by reviewing the completed unit transfers that occurred on our qualified matching service bulletin board during the quarters indicated.

Fiscal Quarter	Low Per Unit Price	High Per Unit Price
2012 1st	$1,390	$1,400
2012 2nd	$1,405	$1,500
2012 3rd	$1,475	$1,600
2012 4th	$1,525	$1,575
2013 1st	$1,265	$1,330
2013 2nd	$1,200	$1,551
2013 3rd	$1,350	$1,605
2013 4th	$1,310	$1,925

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 Granite Falls Energy to be deemed a publicly traded partnership.

DISTRIBUTIONS

Distributions by the Company to our unit holders are in proportion to the number of units held by each unit holder. A unit holder's distribution is determined by multiplying the number of units by distribution per unit declared. Our board of governors has complete discretion over the timing and amount of distributions to our unit holders. However, GFE's Master Loan Agreement with United FCS, PCA provides that we may not declare any distributions other than, for each fiscal year, one or more distributions up to an aggregate of 75% of the net profit (determined according to GAAP) for such fiscal year; provided that the we are and will remain in compliance with all of the covenants, terms and conditions of the Master Loan Agreement. Our expectations with respect to our ability to make future distributions are discussed in greater detail in “MANAGEMENT'S DISCUSSION AND ANALYSIS.” We do not currently have any plans to declare a future distribution.

Below is a table representing the cash distributions declared or paid to the members of Granite Falls Energy during the fiscal years ended October 31, 2013, 2012 and 2011, and subsequent to our fiscal year ended October 31, 2013. Based on the covenants discussed above, all of the below distributions were approved by our lender prior to distribution.

Date Declared to Members of Record:	Total Distribution		Distribution Per Unit		Distributed to Members on:
December 19, 2013	$	5,509,080	$	180	December 31, 2013
October 27, 2011	$	9,196,800	$	300	December 15, 2011
November 23, 2010	$	9,196,800	$	300	December 15, 2010

PERFORMANCE GRAPH

The following graph shows a comparison of cumulative total member return since October 31, 2008, calculated on a dividend reinvested basis, for the Company, the NASDAQ Composite Index (the “NASDAQ”) and an index of other companies that have the same SIC code as the Company (the “Industry Index”). The graph assumes $100 was invested in each of the Company's units, the NASDAQ, and the Industry Index on October 31, 2008. Data points on the graph are annual. Note that historic stock price performance is not necessarily indicative of future unit price performance.

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.

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ITEM 6. SELECTED FINANCIAL DATA

The following table presents selected consolidated financial and operating data as of the dates and for the periods indicated. Due to the acquisition of a majority ownership of HLBE on July 31, 2013, the following information includes consolidated financial and operating data as of the fiscal year 2013 of Granite Falls and the fourth quarter of fiscal year 2013 of Heron Lake. The selected balance sheet financial data as of October 31, 2011, 2010 and 2009 and the selected statement of operations data and other financial data for the years ended October 31, 2010 and 2009 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 October 31, 2013 and 2012 and the selected statement of operations data and other financial data for each of the years in the three-year period ended October 31, 2013 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 consolidated 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 consolidated financial data.

The consolidated financial statements consolidate the operating results and financial position of Granite Falls Energy, LLC and its wholly owned subsidiary, Project Viking, L.L.C. ("Project Viking"), which owns 60.8% of Heron Lake BioEnergy, LLC (“HLBE”). The remaining 39.2% ownership of HLBE is included in the consolidated financial statements as a non-controlling interest.

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Statement of Operations Data for the fiscal years ended October 31,	2013			2012		2011		2010		2009
Revenues	$	224,100,934		$	175,162,043	$	156,521,489	$	95,289,452	$	91,282,031
Cost Goods Sold	210,077,621			172,708,074		142,353,416		85,146,261		87,464,936
Gross Profit	14,023,313			2,453,969		14,168,073		10,143,191		3,817,095
Operating Expenses	2,988,583			2,449,596		2,002,706		1,957,742		2,045,615
Operating Income	11,034,730			4,373		12,165,367		8,185,449		1,771,480
Other Income (Expense)	(475,957		)	156,234		126,489		176,863		(685,300		)
Net Income	10,558,773			160,607		12,291,856		8,362,312		1,086,180
Net Income Attributable to Noncontrolling Interest	526,752			—		—		—		—
Net Income Attributable to Granite Falls Energy, LLC	$	10,032,021		$	160,607	$	12,291,856	$	8,362,312	$	1,086,180
Amounts Attributable to Granite Falls Energy, LLC
Weighted Average Units Outstanding - Basic and Diluted	30,606			30,614		30,656		30,656		30,781
Net Income Per Capital Unit	$	327.78		$	5.25	$	400.96	$	272.78	$	35.29
Distributions per Capital Unit	$	—		$	—	$	600.00	$	150.00	$	—
Balance Sheet Data at October 31,	2013			2012		2011		2010		2009
Current Assets	$	21,469,978		$	20,715,050	$	27,542,361	$	23,429,993	$	14,015,271
Net Property, Plant and Equipment	88,808,855			40,418,082		35,898,961		36,327,497		42,425,018
Goodwill	1,372,473			—		—		—		—
Other Assets	1,021,916			—		—		10,050		32,894
Total Assets	$	112,673,222		$	61,133,132	$	63,441,322	59,767,540		56,473,183
Current Liabilities	11,323,264			6,002,937		13,680,184		3,733,360		4,004,077
Long-Term Debt, less current portion	32,981,955			5,274,870		—		171,298		370,136
Members' Equity:
Members' Equity Attributable to Granite Falls Energy, LLC	59,887,346			49,855,325		49,761,138		55,862,882		52,098,970
Noncontrolling interest	8,480,657			—		—		—		—
Total Members' Equity	$	68,368,003		$	49,855,325	$	49,761,138	$	55,862,882	$	52,098,970
Book Value Per Capital Unit	$	1,956.72		$	1,628.94	$	1,623.21	$	1,822.25	$	1,699.47

* See Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations for further discussion of our financial results.

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

This report contains forward-looking statements that involve future events, our future performance and our expected future operations and actions. In some cases you can identify forward-looking statements by the use of words such as “may,” “will,” “should,” “anticipate,” “believe,” “expect,” “plan,” “future,” “intend,” “could,” “estimate,” “predict,” “hope,” “potential,” “continue,” or the negative of these terms or other similar expressions. These forward-looking statements are only our predictions and involve numerous assumptions, risks and uncertainties. Our actual results or actions may differ materially from these forward-looking statements for many reasons, including the reasons described in this report. We are not under any duty to update the forward-looking statements contained in this report. We cannot guarantee future results, levels of activity, performance or achievements. We caution you not to put undue reliance on any forward-looking statements, which speak only as of the date of this report. You should read this report and the documents that we reference in this report 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.

Overview

Granite Falls Energy, LLC (“Granite Falls Energy” or the “Company”) is a Minnesota Limited Liability Company formed on December 29, 2000.

We are currently producing fuel-grade ethanol, distillers grains and crude corn oil for sale. Our Granite Falls, Minnesota plant has an approximate annual production capacity of 60 million gallons of denatured ethanol, but is currently permitted to produce up to 70 million gallons of undenatured ethanol on a twelve month rolling sum basis. We intend to continue working toward increasing production to take advantage of the additional production allowed pursuant to our permit as long as we believe it is profitable to do so.

On July 31, 2013, we indirectly acquired 63.3% of the outstanding membership units of Heron Lake BioEnergy, LLC (“HLBE”) through our purchase of 100% of the membership units of Project Viking, L.L.C. (“Project Viking”), for a total purchase price of $17,024,500. HLBE owns a 50 million gallon per year ethanol plant located in Heron Lake, Minnesota, but is currently permitted to produce up to 59.2 million gallons. Since this acquisition, we converted all of Project Viking's convertible subordinated notes in HLBE to equity. This conversion, combined with other such conversions by third parties and sales of additional equity by HLBE to third parties, resulted in Project Viking's ownership of 60.8% of the outstanding membership units of HLBE as of October 31, 2013. As a result of Project Viking's majority ownership, under HLBE's member control agreement, Project Viking is entitled to appoint five (5) of the nine (9) governors to HLBE's board of governors. As part of the acquisition, we entered into a Management Services Agreement with HLBE. Under the Management Services Agreement, we agreed to supply our personnel to act as part-time officers and managers of HLBE for the positions of Chief Executive Officer, Chief Financial Officer, and Commodity Risk Manager. The initial term of the Management Services Agreement is three years. At the expiration of the initial term, the Management Services Agreement will automatically renew for successive one-year terms unless and until either party gives the other party 90 days written notice of termination prior to expiration of the initial term or the start of a renewal term. The Management Services Agreement may also be terminated by either party for cause under certain circumstances.

Our operating results are largely driven by the prices at which we sell our ethanol, distillers grains, and corn oil as well as the costs related to their production. The price of ethanol has historically fluctuated with the price of petroleum-based products such as unleaded gasoline, heating oil and crude oil. The price of distillers grains has historically been influenced by the price of corn as a substitute livestock feed. We expect these price relationships to continue for the foreseeable future, although recent volatility in the commodities markets makes historical price relationships less reliable. Our largest costs of production are corn, natural gas, depreciation and manufacturing chemicals. Our cost of corn is largely impacted by geopolitical supply and demand factors and the outcome of our risk management strategies. Prices for natural gas, manufacturing chemicals and denaturant are tied directly to the overall energy sector, crude oil and unleaded gasoline.

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Results of Operations for the Fiscal Years Ended October 31, 2013 and 2012

The following table shows the results of our operations and the percentage of revenues, costs of goods sold, operating expenses and other items to total revenues in our audited statements of operations for the fiscal years ended October 31, 2013 and 2012:

	2013					2012
Income Statement Data	Amount			%		Amount		%
Revenue	$	224,100,934		100.0	%	175,162,043		100.0	%
Cost of Goods Sold	210,077,621			93.7	%	172,708,074		98.6	%
Gross Profit	14,023,313			6.3	%	2,453,969		1.4	%
Operating Expenses	2,988,583			1.3	%	2,449,596		1.4	%
Operating Income	11,034,730			4.9	%	4,373		—	%
Other Income (Expense), net	(475,957		)	(0.2	)%	156,234		0.1	%
Net Income	$	10,558,773		4.7	%	$	160,607	0.1	%
Net Income attributable to Noncontrolling interest	$	526,752		0.2	%	$	—	—	%
Net Income attributable to Granite Falls Energy, LLC	$	10,032,021		4.5	%	$	160,607	0.1	%

Revenues

Our revenues from operations come from three primary sources: sales of fuel ethanol, sales of distillers grains and sales of corn oil.

The following table shows the sources of our revenue for the fiscal year ended October 31, 2013:

Revenue Sources	Amount		Percentage of Total Revenues
Ethanol sales	$	173,032,042	77.2	%
Distillers grains sales	44,137,409		19.7	%
Corn oil sales	6,482,239		2.9	%
Other/Miscellaneous	449,244		0.2	%
Total Revenues	$	224,100,934	100.0	%

The following table shows the sources of our revenue for the fiscal year ended October 31, 2012:

Revenue Sources	Amount		Percentage of Total Revenues
Ethanol sales	$	138,628,048	79.1	%
Distillers grains sales	32,214,496		18.4	%
Corn oil sales	4,319,499		2.5	%
Total Revenues	$	175,162,043	100.0	%

We experienced a 27.9% increase in our revenues for our 2013 fiscal year compared to our 2012 fiscal year. Management attributes this increase in revenues primarily to an increase in the quantities sold as a result of our indirect acquisition of HLBE, since its results of operations were consolidated into our statements of operations beginning as of our fourth fiscal quarter in 2013 . For our 2013 fiscal year, ethanol sales comprised approximately 77.2% of our revenue, distillers grains comprised approximately 19.7% of our revenue and corn oil sales comprised approximately 2.9% of our revenue. For our 2012 fiscal year, ethanol sales comprised approximately 79.1% of our revenue, distillers grains comprised approximately 18.4% of our revenue and corn oil sales comprised approximately 2.5% of our revenue.

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Ethanol

The average price we received for our ethanol remained steady during our 2013 fiscal year compared to our 2012 fiscal year. Our average price per gallon of ethanol sold was $2.24 in 2013 and $2.23 in 2012. We also experienced a 24.3% increase in the number of gallons sold in our fiscal year ended October 31, 2013, primarily as a result of the HLBE acquisition, although we also sold 3.4% more gallons at our Granite Falls plant in fiscal year 2013 compared to the prior year. Management anticipates that if the U.S. Environmental Protection Agency's ("EPA's") proposed rule reducing Renewable Fuels Standard ("RFS") levels for 2014 from the statutory volume becomes effective, domestic demand for ethanol could decrease and ethanol prices may decrease.

Distillers Grains

We produce distillers grains for sale in two separate forms, distillers dried grains with solubles (DDGS) and modified/wet distillers grains (MWDG). Market factors dictate whether we sell more DDGS versus MWDG.

Distillers grains represent a slightly larger portion of our revenues during our 2013 fiscal year compared to our 2012 fiscal year as a result of higher prices and greater quantities of distillers grains sold. The price we received for our distillers grains in our 2013 fiscal year was approximately 7.8% higher than the price we received during our 2012 fiscal year. Management believes these higher distillers grains prices are a result of the high price of other feed products available to livestock producers during much of our 2013 fiscal year. More recently, the price of other feed products has decreased in connection with a record 2013 corn harvest. We anticipate that the market price of our distillers grains will continue to be volatile as a result of changes in the price of corn and competing animal feed substitutes such as soybean meal. Volatility in distillers grains supplies related to changes in ethanol production is another factor that may impact the sales price of our distillers grains. Additionally, our quantity of distillers grains sold increased approximately 27.1% in our 2013 fiscal year compared to our 2012 fiscal year. This increase in quantity sold was largely a result of the HLBE acquisition, although we also sold 6.4% more distillers grains at our Granite Falls plant in fiscal year 2013 compared to the prior year. The price and quantity increases, combined with the relatively smaller increases in ethanol prices and quantities discussed above, resulted in distillers grains sales comprising a larger percentage of our total revenues during our 2013 fiscal year relative to our 2012 fiscal year.

Corn Oil

Separating the corn oil from our distillers grains decreases the total tons of distillers grains that wesell; however, our corn oil has a higher per ton value than our distillers grains. The average price we received per pound of corn oil sold during our 2013 fiscal year was approximately 8.7% less than the average price received during our 2012 fiscal year. Management attributes the decrease in corn oil prices to additional corn oil entering the market. However, increased use of corn oil by biodiesel producers and animal feeders have continued to support demand.

Offsetting this price decrease, our volume of corn oil sold increased approximately 64.3% during our 2013 fiscal year relative to our 2012 fiscal year as a result of the HLBE acquisition and a 34.8% increase in quantities sold at our Granite Falls plant due to increased extraction efficiencies. The net effect of the price decrease and increase in volume sold was an increase in corn oil revenue from $4,319,499 in 2012 to $6,482,239 in 2013.

Hedging and Volatility of Sales

We occasionally engage in hedging activities with respect to our ethanol sales. We recognize the gains or losses that result from the changes in the value of these derivative instruments in revenues as the changes occur. As ethanol prices fluctuate, the value of our derivative instruments are impacted, which affects our financial performance. However, we did not have any ethanol related derivative instruments other than forward sales contracts as discussed below under "Commodity Price Risk Protection."

Our results of operations for our 2014 fiscal year will continue to be affected by volatility in the commodity markets. Management believes the industry will need to continue to grow demand and further develop an ethanol distribution system to facilitate additional blending of ethanol and gasoline to offset oversupply issues within the industry. The EPA's approval of E15 for use in certain vehicles has led us to be optimistic that over time, as E15 is brought to market and gains market acceptance, demand for ethanol will increase. However, we do not anticipate that the EPA's approval of E15 will impact ethanol demand or pricing in the near term. Additionally, any reduction in or waiver of RFS levels may negatively impact demand for ethanol.

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Cost of Sales

Our two primary costs of producing ethanol, distillers grains and corn oil are corn costs and natural gas costs. We experienced an increase in our cost of goods sold for our 2013 fiscal year compared to our 2012 fiscal year. Our cost of goods sold increased to $210,077,621 for our fiscal year ended October 31, 2013 from $172,708,074 in our fiscal year ended October 31, 2012.

Our costs of goods sold as a percentage of revenues were 93.7% for our fiscal year ended October 31, 2013 compared to 98.6% for the same period of 2012. Our two largest costs of production are corn (82.5% of cost of goods sold for our fiscal year ended October 31, 2013) and natural gas (4.2% of cost of goods sold for our fiscal year ended October 31, 2013).

Corn Costs

We experienced an increase of approximately 18.5% in the total amount we paid for corn for our 2013 fiscal year compared to our 2012 fiscal year. This was the net result of a 26.8% increase in the quantity of bushels we purchased, offset by a 6.6% decrease in our per bushel cost. A tight corn supply following the 2012 harvest put upward pressure on corn prices throughout much of our 2013 fiscal year. However, the record 2013 corn harvest eased prices substantially in our fourth fiscal quarter. Due to the 2013 harvest, we expect corn prices to remain lower over the next several months than what we have experienced during the fist several months of our 2013 fiscal year.

Natural Gas Costs

For our 2013 fiscal year, we experienced an increase of approximately 47.7% in our overall natural gas costs compared to our 2012 fiscal year. This increase was primarily the result of the HLBE acquisition (approximately $1.8 million, or a 30% increase), although we also experienced a 15.6% in natural gas costs at our Granite Falls plant in fiscal year 2013 compared to the prior year. We expect the market price for natural gas to remain steady in the near term as we continue to enjoy an abundant supply of domestic natural gas, due in part to the continued commissioning of new, highly productive natural gas wells.

Hedging and Volatility of Purchases

Realized and unrealized gains and losses related to our corn derivative instruments resulted in an increase of $155,563 in our cost of goods sold for our 2013 fiscal year compared to a decrease of $1,651,799 in our cost of goods sold for our 2012 fiscal year.  We recognize the gains or losses that result from the changes in the value of our derivative instruments related to corn in cost of goods sold as the changes occur.  As corn prices fluctuate, the value of our derivative instruments are impacted, which affects our financial performance.  We anticipate continued volatility in our cost of goods sold due to the timing of the changes in value of the derivative instruments relative to the cost and use of the commodity being hedged. 

Operating Expense

Operating expenses as a percentage of revenues were steady, decreasing from 1.4% of revenues for our fiscal year ended October 31, 2012 to 1.3% of revenues for our fiscal year ended October 31, 2013. We continue to focus on increasing our operating efficiency as we strive to lower our operating expenses. We expect that going forward our operating expenses will remain relatively steady.

Operating Income

Our income from operations for our fiscal year ended October 31, 2013 was 4.9% of our revenues compared to income of a negligible amount of our revenues for our fiscal year ended October 31, 2012. For our fiscal year ended October 31, 2013, we reported operating income of $11,034,730 and for our fiscal year ended October 31, 2012, we had operating income of $4,373.

Other Income (Expense), Net

We had total other expense for our fiscal year ended October 31, 2013 of $475,957, compared to total other income of $156,234 for our fiscal year ended October 31, 2012. We had an increase in interest expense during our fiscal year ended October 31, 2013 compared to the same period of 2012 due to increased borrowings on our credit facilities, including the facilities of HLBE.

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Additionally, our other income, net decreased from $182,186 of income for our fiscal year ended October 31, 2012 to $48,373 of expense for our fiscal year ended October 31, 2013.

Results of Operations

Comparison of Fiscal Years Ended October 31, 2012 and 2011

	2012			2011
Income Statement Data	Amount		%	Amount		%
Revenues	$	175,162,043	100.0	$	156,521,489	100.0
Cost of Goods Sold	172,708,074		98.6	142,353,416		90.9
Gross Profit	2,453,969		1.4	14,168,073		9.1
Operating Expenses	2,449,596		1.4	2,002,706		1.3
Operating Income	4,373		—	12,165,367		7.8
Other Income, net	156,234		0.1	126,489		0.1
Net Income	$	160,607	0.1	$	12,291,856	7.9

Revenues

The following table shows the sources of our revenue for the year ended October 31, 2012.

Revenue Sources	Amount		Percentage of Total Revenues
Ethanol sales	$	138,628,048	79.1	%
Distillers grains sales		32,214,496	18.4	%
Corn oil sales		4,319,499	2.5	%
Total Revenues	$	175,162,043	100.0	%

The following table shows the sources of our revenue for the year ended October 31, 2011:

Revenue Sources	Amount			Percentage of Total Revenues
Ethanol sales	$	129,936,623		83.0	%
Distillers grains sales		22,745,766		14.5	%
Corn oil sales		3,843,726		2.5	%
Ethanol derivative activity losses		(4,626	)	—	%
Total Revenues	$	156,521,489		100.0	%

We experienced an 11.9% increase in our revenues for our 2012 fiscal year compared to our 2011 fiscal year. Management attributes this increase in revenues primarily to an increase in the production of our products. Our volume of ethanol sold in 2012 was approximately15.4% higher than the volume sold in 2011. For our 2012 fiscal year, ethanol sales comprised approximately 79.1% of our revenue, distillers grains comprised approximately 18.4% of our revenue and corn oil sales comprised approximately 2.5% of our revenue. For our 2011 fiscal year, ethanol sales comprised approximately 83.0% of our revenue, distillers grains comprised approximately 14.5% of our revenue and corn oil sales comprised approximately 2.5% of our revenue.

Ethanol

The average price we received for our ethanol decreased by approximately 7.5% during our 2012 fiscal year compared to our 2011 fiscal year. Management attributes this decrease in our average ethanol sales price to sustained market oversupply resulting form anticipation of the Federal Volumetric Ethanol Tax Credit "VEETC") on December 31, 2011. In an effort to capture as much of the VEETC as possible, blenders maximized the amount of ethanol they could blend at the end of calendar 2011. As a result of that timing, demand slowed during the beginning of calendar 2012, resulting in increased ethanol inventories, which pressured ethanol prices downward.

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Distillers Grains

Distillers grains represent a larger portion of our revenues during our 2012 fiscal year compared to our 2011 fiscal year as a result of higher prices and greater quantities of distillers grains produced and sold. The price we received for our distillers grains in our 2012 fiscal year was approximately 25.2% higher than the price we received during our 2011 fiscal year. Management believes these higher distillers grains prices are a result of the high price of other feed products available to livestock producers. Additionally, our quantity of distillers grains sold increased approximately 13.1% in our 2012 fiscal year compared to our 2011 fiscal year. This increase in quantity sold was largely a result of increased production of our products during our 2012 fiscal year compared to our 2011 fiscal year. The price and quantity increases, combined with the decrease in ethanol prices discussed above, resulted in distillers grains sales comprising a larger percentage of our total revenues during our 2012 fiscal year relative to our 2011 fiscal year.

Corn Oil

The average price we received per pound of corn oil sold during our 2012 fiscal year was approximately 8.9% less than the average price received during our 2011 fiscal year. Management attributes the decrease in corn oil prices to additional corn oil entering the market. However, increased use of corn oil by biodiesel producers and animal feeders have continued to support demand.

Offsetting this price decrease, our volume of corn oil sold increased approximately 23.3% during our 2012 fiscal year relative to our 2011 fiscal year as a result of higher production rates at our facility and increased extraction efficiencies. The net effect of the price decrease and increase in volume sold was an increase in corn oil revenue from $3,843,726 in 2011 to $4,319,499 in 2012.

Cost of Goods Sold and Gross Profit

Our costs of goods sold as a percentage of revenues were 98.6% for our fiscal year ended October 31, 2012 compared to 90.9% for the same period of 2011. Our two largest costs of production were corn (84.7% of cost of goods sold for our fiscal year ended October 31, 2012) and natural gas (3.4% of cost of goods sold for our fiscal year ended October 31, 2012). Our cost of goods sold increased to $172,708,074 for our fiscal year ended October 31, 2012 from $142,353,416 in our fiscal year ended October 31, 2011. Our per bushel corn costs increased by approximately 8.8% for the year ended October 31, 2012 as compared to the same period for our 2011 fiscal year. Additionally, our volume of corn used in our 2012 fiscal year was approximately 13.5% greater as compared to our 2011 fiscal year due to increased production. Our increased cost and volume of corn were the primary factors driving up our costs of goods sold.

Corn Costs

We experienced an increase of approximately 23.5% in the total amount we paid for corn for our 2012 fiscal year compared to our 2011 fiscal year. This increase was primarily due to our increased per bushel cost and volume of corn used discussed above. Widespread drought in 2012 in several corn producing states, combined with continued corn demand from other sectors, resulted in increasing corn prices.

Natural Gas Costs

We experienced a decrease of approximately 15.9% in our overall natural gas costs in our 2012 fiscal year compared to our 2011 fiscal year. Falling natural gas prices decreased our natural gas costs, even though our natural gas consumption rose as a result of our increased ethanol production during our 2012 fiscal year as compared to our 2011 fiscal year.

Hedging

Realized and unrealized gains and losses related to our corn derivative instruments resulted in a decrease of $1,651,799 in our cost of goods sold for our 2012 fiscal year compared to an increase of $1,280,413 in our cost of goods sold for our 2011 fiscal year. We recognize the gains or losses that result from the changes in the value of our derivative instruments related to corn, natural gas, and denaturant in cost of goods sold as the changes occur. As corn, natural gas, and denaturant prices fluctuate, the value of our derivative instruments are impacted, which affects our financial performance. We anticipate continued volatility in our cost of goods sold due to the timing of the changes in value of the derivative instruments relative to the cost and use of the commodity being hedged.

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Operating Expenses

Operating expenses as a percentage were relatively steady for the fiscal year ended October 31, 2012 compared to the same period in 2011. Our operating expenses as a percentage of revenues were 1.4% for the fiscal year ended October 31, 2012 and 1.3% for the same period ended October 31, 2011.

Other Income, Net

We had other income, net for our fiscal year ended October 31, 2012 of $156,234 compared to other income of $126,489 for our fiscal year ended October 31, 2011. Our other income, net increased from $37,281 for our fiscal year ended October 31, 2011 to $182,186 for our fiscal year ended October 31, 2012 primarily as a result of income related to land rent and other miscellaneous income.

Our interest income was lower for our fiscal year ended October 31, 2012 compared to the same period of 2011 as a result of having less cash on hand during the 2012 period. Our interest expense was greater for our fiscal year ended October 31, 2012 compared to the same period of 2011 due to the note we took to purchase a Shuttlewagon Railcar Mover in December 2011.

Changes in Financial Condition for the Fiscal Year Ended October 31, 2013 and 2012

The following table highlights the changes in our financial condition for the fiscal year ended ended October 31, 2013 from our previous fiscal year ended October 31, 2012:

	October 31, 2013		October 31, 2012
Current Assets	$	21,469,978	$	20,715,050
Total Assets	$	112,673,222	$	61,133,132
Current Liabilities	$	11,323,264	$	6,002,937
Long-Term Debt	$	32,981,955	$	5,274,870
Members' Equity attributable to Granite Falls Energy, LLC	$	59,887,346	$	49,855,325
Noncontrolling Interest	$	8,480,657	$	—

Total assets were $112,673,222 at October 31, 2013 compared to $61,133,132 at October 31, 2012, primarily as a result of an increase in property, plant and equipment related to our indirect acquisition of majority ownership of HLBE. As a result of this acquisition, our assets now also include $1,372,473 in goodwill and $1,021,916 in other assets.

Current assets totaled $21,469,978 at October 31, 2013, which is more than our current assets as of October 31, 2012 which totaled $20,715,050. The increase is primarily due to an increase in cash and prepaid expenses and other current assets, offset slightly by a decrease in accounts receivable.

Total current liabilities increased and totaled $11,323,264 at October 31, 2013 and approximately $6,002,937 at October 31, 2012. This increase was primarily the result of an increase in the current portion of our long-term debt and and increase in our corn payable to FCE.

Long-term debt totaled $32,981,955 at October 31, 2013 which is more than our long-term debt as of October 31, 2012 which totaled $5,274,870. The increase was primarily the result of the consolidation of HLBE’s debt facilities due to the indirect acquisition of a majority ownership of HLBE during the year.

Members’ equity attributable to Granite Falls Energy, LLC totaled $59,887,346 at October 31, 2013 which is more than our Members’ equity attributable to Granite Falls Energy, LLC as of October 31, 2012 which totaled $49,855,325. The increase was directly related to the net income attributable to Granite Falls Energy, LLC of $10,032,021 for the year ended October 31, 2013.

Noncontrolling interest totaled $8,480,657 at October 31, 2013 compared to $0 at October 31, 2012.  This is directly related to recognition of the 36.6% noncontrolling interest in HLBE at the date of the GFE acquisition along with the issuance of subsidiary units and net income attributable to the noncontrolling interest during the fourth quarter of fiscal 2013.

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Plant Operations

We are currently producing fuel-grade ethanol, distillers grains and crude corn oil for sale. Our Granite Falls plant has an approximate annual production capacity of 60 million gallons of denatured ethanol. We have obtained an amendment to our environmental permits allowing us to produce up to 70 million gallons of undenatured ethanol on a twelve month rolling sum basis. Our Heron Lake plant has an approximate annual production capacity of 50 million gallon per year, but is currently permitted to produce up to 59.2 million gallons.We intend to continue working to increase production to take advantage of the underutilized capacity of our plants.  Any plant bottlenecks are assessed and a cost benefit analysis is performed prior to further capital investment.

We have completed several de-bottlenecking projects at our Granite Falls plant and we are in the process of completing our remaining projects. Each of these projects helps our facility to be more efficient, productive and improve the environmental aspects of our process. For the fiscal year ended October 31, 2013, we have incurred approximately $1,342,000 in costs associated with our equipment construction projects. Since starting our de-bottlenecking projects we have incurred approximately $6,477,000 associated with the cost of these equipment improvements.

We expect to have sufficient cash generated by continuing operations, current lines of credit and cash reserves to cover our usual operating costs, which consist primarily of our corn and natural gas supply, de-bottlenecking projects, staffing and office expense, audit and legal compliance, working capital costs and debt service obligations.

Trends and Uncertainties Impacting the Ethanol and Distillers Grains Industries and Our Future Revenues

Our revenues primarily consist of sales of the ethanol and distillers grains we produce; however, we also realize revenue from the sale of corn oil we separate from our distillers syrup. The ethanol industry needs to continue to expand the market for ethanol and distillers grains in order to maintain current price levels.

The following chart shows the average cash price per gallon of ethanol in the United States from December 2011 through October 2013, as compiled with data from the USDA National Agricultural Statistics Service.

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According to the Renewable Fuels Association (“RFA”), as of January 6, 2014, there were 211 ethanol plants nationwide with the capacity to produce approximately 14.8 billion gallons of ethanol annually. The RFA estimates that the operating production nationwide is approximately 13.6 billion gallons of ethanol annually and that approximately 8% of the nameplate production capacity is not currently operational. Management believes the production capacity of the ethanol industry is greater than ethanol demand which may continue to depress ethanol prices.

Currently, ethanol is primarily blended with conventional gasoline for use in standard (non-flex fuel) vehicles to create a blend which is 10% ethanol and 90% conventional gasoline. Estimates indicate that approximately 135 billion gallons of gasoline are sold in the United States each year. However, gasoline demand may be shrinking in the United States as a result of the global economic slowdown and improved fuel efficiency. Assuming that all gasoline in the United States is blended at a rate of 10% ethanol and 90% gasoline, the maximum demand for ethanol is 13.5 billion gallons. This is commonly referred to as the “blend wall”, which represents a limit where more ethanol cannot be blended into the national gasoline pool. This is a theoretical limit since it is believed it would not be possible to blend ethanol into every gallon of gasoline that is used in the United States and it discounts higher percentage blends of ethanol such as E15 and E85 used in flex fuel vehicles. In April 2012, the U.S. Environmental Protection Agency ("EPA") approved the first applications for registering ethanol for use in making E15. As E15 is brought to market and gains market acceptance, management believes that demand for ethanol will increase. However, we do not expect the EPA's acceptance of applications for registering ethanol for use in making E15 to impact ethanol demand or pricing in the near term.

The United States ethanol industry has exported an increasing amount of ethanol. Granite Falls Energy, through the use of its ethanol marketer, has exported a portion of its ethanol production to the European market. The exportation of domestic ethanol has helped to mitigate the effects of the blend wall and has thereby helped to maintain ethanol price levels. We are excited to be participating in the export market, but would prefer that all of our domestically produced fuel could be utilized by the domestic market. Whether the export market continues to make economic sense for Granite Falls Energy will depend on domestic blend rates as well as global supply and demand for our product.

The federal Renewable Fuels Standard, known as RFS2, requires the use of a specified amount of renewable fuels in the United States. In 2013, RFS2 required approximately 16.55 billion gallons, of which corn based ethanol could be used to satisfy approximately 13.8 billion gallons. If the mandate is not changed, in 2014, the RFS2 will require approximately 18.15 billion gallons, of which corn based ethanol can be used to satisfy approximately 14.4 billion gallons. However, in November 2013 the EPA issued a proposed rule that would reduce the RFS2 levels for 2014 from the statutory volume requirement of 18.15 billion gallons to 15.21 billion gallons, and reduce the renewable volume obligations that can be satisfied by corn-based ethanol from 14.4 billion gallons to 13 billion gallons, which is less than the 2013 volume requirement of 13.8 billion gallons. If the EPA's proposal becomes a final rule, or if RFS2 were to be otherwise reduced or eliminated by the exercise of the EPA's waiver authority or by Congress, the demand for ethanol may be negatively impacted.

Trends and Uncertainties Impacting the Corn and Natural Gas Markets and Our Future Cost of Goods Sold

Our costs of our goods sold consist primarily of costs relating to the corn and natural gas supplies necessary to produce ethanol and distillers grains for sale. We grind approximately 1,800,000 bushels of corn each month at the Granite Falls plant and approximately 1,640,000 bushels of corn each month at the Heron Lake plant. For the fiscal year ended October 31, 2013, our average cost of corn per bushel, net of hedging activity, was approximately $0.454 lower than our per bushel cost of corn for the same period ended October 31, 2012.

Corn prices remain above historical averages. A widespread drought during the 2012 growing season in several corn producing states, combined with continued corn demand from other sectors, resulted in increasing corn prices for much of our 2013 fiscal year. However, the 2013 corn harvest set domestic records for bushels harvested. This led to a decrease in corn prices during the fourth fiscal quarter of our 2013 fiscal year. We expect corn prices to remain comparatively lower during the next several months. If corn prices increase again, and if a period of high corn prices were to be sustained for some time, such pricing may reduce our ability to generate income because of the higher cost of operating our plant.

Natural gas is also an important input commodity to our manufacturing process. Our natural gas usage is approximately 120,000 million British thermal units (mmBTU) per month at the Granite Falls plant and approximately 138,000 mmBTU per month at the Heron Lake plant. We continue to work to find ways to limit our natural gas price risk through efficient usage practices, research of new technologies, and pricing and hedging strategies. We use a marketing firm and an energy consultant for our natural gas procurement and will work with them on an ongoing basis to mitigate our exposure to volatile gas prices.

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Management anticipates that natural gas prices will be relatively stable in the next several months as a result of ample amount of gas in the supply chain. However, should we experience any natural gas supply disruptions, including disruptions from hurricane activity, we may experience significant increases in natural gas prices.

Compliance with Environmental Laws

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 plant. As such, any changes that are made to the plant or its operations must be reviewed to determine if amended permits need to be obtained in order to implement these changes.

Contracting Activity

Farmers Cooperative Elevator Company supplies corn to our Granite Falls plant. We do not have an exclusive corn supplier for the Heron Lake plant. Eco-Energy, LLC markets our ethanol at both plants and RPMG markets our distillers grains at the Granite Falls plant and our corn oil at both plants. Gavilon markets our distillers grains at the Heron Lake plant. Each of these contracts is critical to our success and we are very dependent on each of these companies. Accordingly, the financial stability of these partners is critical to the successful operation of our business.

We independently market a small portion of our ethanol production as E-85 to local retailers.

Commodity Price Risk Protection

We seek to minimize the risks from fluctuations in the prices of corn, ethanol, denaturant and natural gas through the use of derivative instruments. In practice, as markets move, we actively manage our risk and adjust hedging strategies as appropriate. We do not use hedge accounting which would match the gain or loss on our hedge positions to the specific commodity contracts being hedged. Instead, we are using fair value accounting for our hedge positions, which means that as the current market price of our hedge positions changes, the gains and losses are immediately recognized in our revenue or cost of goods sold depending on the commodity that is hedged. 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 October 31, 2013, we recorded a net liability for our derivative instruments in the amount of $75,113. As of October 31, 2012, we recorded a net liability for our derivative instruments in the amount of $45,563. There are several variables that could affect the extent to which our derivative instruments are impacted by fluctuations in the price of corn, ethanol, denaturant or natural gas. However, it is likely that commodity cash prices will have the greatest impact on the derivative instruments with delivery dates nearest the current cash price. As we move forward, additional protection may be necessary. As the prices of these hedged commodities move in reaction to market trends and information, our statement of operations will be affected depending on the impact such market movements have on the value of our derivative instruments. Depending on market movements, crop prospects and weather, these price protection positions may cause immediate adverse effects, but are expected to produce long-term positive growth for Granite Falls Energy.

As of October 31, 2013, GFE had forward contracts to sell approximately $6,283,000 of ethanol for various periods through December 2013. GFE also had forward contracts to sell approximately $3,052,000 of distillers grains for delivery through March 2014 as of October 31, 2013.

As of October 31, 2013, GFE had approximately 350,000 bushels of fixed basis contracts for forward corn purchase commitments for delivery in November 2013. Through these contracts we hope to minimize risk from future market price fluctuations and basis fluctuations.

As of October 31, 2013, GFE had no forward purchase contracts to purchase natural gas. As we move forward, we may determine that additional price protection for natural gas purchases is necessary to reduce our susceptibility to price increases. However, we may not be able to secure natural gas for prices less than current market price and we may not recover high costs of production resulting from high natural gas prices, which may raise our costs of production and reduce our net income.

As of October 31, 2013, HLBE did not have any ethanol or corn derivative instruments. HLBE had natural gas agreements with a minimum commitment of approximately 1.6 million MMBTU per year until October 31, 2014.

The derivative accounts are reported at fair value. We have categorized the cash flows related to the hedging activities with cash provided by operations, in the same category as the item being hedged.

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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:

Inventory

We value our inventory at the lower of cost or market. Our estimates are based upon assumptions believed to be reasonable, but which are inherently uncertain and unpredictable. These valuations require the use of management’s assumptions which do not reflect unanticipated events and circumstances that may occur. In our analysis, we consider future corn costs and ethanol prices, break-even points for our plant and our risk management strategies in place through our use of derivative instruments. Given the significant assumptions required and the possibility that actual conditions will differ, we consider the valuation of the lower of cost or market on inventory to be a critical accounting estimate.

Property, Plant and Equipment

Management’s estimate of the depreciable lives of property, plant, and equipment is based on the estimated useful lives. We review long-lived assets for impairment whenever events or changes in circumstances indicate that the related carrying amounts may not be recoverable. Impairment testing for assets requires various estimates and assumptions, including an allocation of cash flows to those assets and, if required, an estimate of the fair value of those assets. Given the significant assumptions required and the possibility that actual conditions will differ, we consider the assessment of the useful lives of property and equipment to be a critical accounting estimate.

Accounting for Business Combinations

In accounting for business combinations, we apply the accounting requirements of ASC 805, “Business Combinations,” (“ASC 805”), which requires the recording of net assets of acquired businesses at fair value. In developing estimates of fair value of acquired assets and assumed liabilities, we analyze a variety of factors including market data, estimated future cash flows of the acquired operations, industry growth rates and assumptions for certain future commodity prices. Such a valuation requires management to make significant estimates and assumptions, especially with respect to the future commodity prices.

In determining the fair value of the Company’s assets associated with the purchase of HBLE on July 31, 2013, we utilized the following valuation methods:

• Market approach: This method estimates fair value based on market prices in actual transactions and on asking prices for assets currently available for sale. This valuation process is essentially that of comparison and correlation between other similar assets and those of HLBE.

• Cost approach: This method estimates fair value based on the replacement cost of a comparable asset at prices at the time of the acquisition reduced for depreciation of the asset.

See Note 3 of the Notes to the Consolidated Financial Statements for a further discussion of the acquisition of HLBE.

Liquidity and Capital Resources

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

	2013			2012
Net cash provided by (used in) operating activities	$	22,715,888		$	(953,958	)
Net cash used in investing activities	$	(9,073,284	)	$	(7,551,142	)
Net cash used in financing activities	$	(13,169,658	)	$	(3,873,632	)

Operating Cash Flows.Cash provided by operating activities was $22,715,888 for the fiscal year endedOctober 31, 2013, compared to cash used in operating activities of approximately $953,958 for the fiscal year endedOctober 31, 2012. The difference is primarily attributable to an increase in net income for the fiscal year ended October 31, 2013 compared to the

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fiscal year ended October 31, 2012. We also had significant changes in accounts receivable and inventory during the fiscal year ended October 31, 2013 compared to the fiscal year ended October 31, 2012, which provided cash flow from operating activities of approximately $3,911,000 and $1,946,000, respectively. Currently, our capital needs are being adequately met through cash flows from our operating activities and our currently available credit facilities.

Investing Cash Flows.Cash used in investing activities was $9,073,284 for the fiscal year endedOctober 31, 2013, compared to cash used in investing activities of $7,551,142 for the fiscal year endedOctober 31, 2012. During the fiscal year endedOctober 31, 2013, we used approximately $6,977,000 to indirectly acquire a majority interest in HLBE. Additionally, during our 2013 fiscal year we used cash totaling approximately $2,636,000 for capital expenditures, construction in process and land acquisitions, compared to payments of approximately $7,551,000 during the same period in 2012. We also had proceeds of $540,000 during fiscal 2013 related to the sale of land.

Financing Cash Flows.Cash used in financing activities was $13,169,658 for the fiscal year endedOctober 31, 2013, compared to $3,873,632 for the fiscal year endedOctober 31, 2012. The difference is primarily attributable to increases in payments on our long-term debt associated with our credit facilities during our 2013 fiscal year. We also received proceeds from the issuance of subordinated convertible notes in fiscal year 2013, discussed below under "Indebtedness." In our 2012 fiscal year, we received proceeds from our long-term debt and also paid a member distribution.

The following table shows our cash flows for the fiscal years ended October 31, 2012 and 2011:

	2012			2011
Net cash provided by (used in) operating activities	$	(953,958	)	$	11,879,586
Net cash used in investing activities	$	(7,551,142	)	$	(50,020	)
Net cash used in financing activities	$	(3,873,632	)	$	(9,429,231	)

Operating Cash Flows.Cash used in operating activities was approximately $954,000 for the fiscal year ended October 31, 2012, compared to cash provided by operating activities of approximately $11,880,000 for the fiscal year ended October 31, 2011. The difference is primarily attributable to our decrease in net income for the fiscal year ended October 31, 2012 compared to the fiscal year ended October 31, 2011. We also purchased approximately $6,500,000 of corn during the fourth quarter of 2012 that we used during fiscal 2013.

Investing Cash Flows.Cash used in investing activities was approximately $7,551,000 for the fiscal year ended October 31, 2012, compared to cash used in investing activities of approximately $50,000 for the fiscal year ended October 31, 2011. During the fiscal year ended October 31, 2012, we made payments totaling approximately $7,551,000 for capital expenditures, construction in process and land acquisitions, compared to payments of approximately $3,550,000 during the same period in 2011. Additionally, during the fiscal year ended October 31, 2011 we had positive investing cash flow from the maturity of certain short term investments (certificates of deposit) in the amount of $3,500,000.

Financing Cash Flows.Cash used in financing activities was approximately $3,874,000 for the fiscal year ended October 31, 2012, compared to approximately $9,429,000 for the fiscal year ended October 31, 2011. The difference is primarily attributable to approximately $5,491,000 in long-term debt proceeds from our revolving term loan with United FCS during the fiscal year ended October 31, 2012.

Indebtedness

Granite Falls Energy

Short-Term Debt Sources

In August 2012, we entered into two new credit facilities, one short-term and one long-term, with United FCS. CoBank serves as administrative agent for these new credit facilities. The Company's short-term credit facility with United FCS is a revolving line of credit. This facility allows us to borrow, repay, and reborrow up to $6,000,000 subject to a borrowing base calculation. Final payment of amounts borrowed under this credit facility is due August 1, 2014. Amounts borrowed under the revolving line of credit bear interest at one of three interest rate options selected by us, (i) at a variable weekly rate equal to 2.65% above the rate quoted by the British Bankers Association for the offering of one-month U.S. Dollar deposits, (ii) at a fixed rate to be quoted by CoBank, or (iii) at a fixed rate for up to 12 months equal to LIBOR plus 2.65%. Interest on amounts borrowed is payable monthly in arrears. We expect to utilize this credit facility to finance inventory and receivables as needed. We have not yet made any advances on this line of credit.

28

The Company also has letters of credit totaling $337,928 as part of a credit requirement of Northern Natural Gas. In August 2012, these letters of credit were transferred to United FCS as part of the new credit facilities. These letters of credit reduce the amount available under our line of credit to approximately $5,662,000.

Long-Term Debt Sources

The Company's long-term credit facility with United FCS is a revolving term loan. Under this facility we may borrow, repay, and reborrow up to $8,000,000. However, the amount available for borrowing under this facility reduces by $1,000,000 every six months, beginning September 1, 2013, with final payment due March 1, 2017. Therefore, at October 31, 2013, the amount we may borrow under this facility is $7,000,000. Amounts borrowed under the revolving term loan bear interest at one of three interest rate options selected by us, (i) at a variable weekly rate equal to 2.90% above the rate quoted by the British Bankers Association for the offering of one-month U.S. Dollar deposits, (ii) at a fixed rate to be quoted by CoBank, or (iii) at a fixed rate for up to 12 months equal to LIBOR plus 2.90%. Interest on amounts borrowed is payable monthly in arrears. We have used this credit facility to fund our rail infrastructure improvement project. As of October 31, 2012, the outstanding balance on our revolving term loan was $2,513,674 and the interest rate as of that date was 3.22%.

The Company's credit facilities with United FCS require the Company to comply with certain financial covenants, including (i) maintaining working capital of at least $10,000,000, (ii) maintaining local net worth, defined as total assets, minus total liabilities, minus investments by the Company in other entities, of at least $45,000,000, and (iii) achieving a debt service coverage ratio of at least 2.0 to 1.0. Our debt service coverage ratio is calculated as follows: (1) net income, plus depreciation and amortization, minus extraordinary gains (plus extraordinary losses), minus gain on asset sales (plus loss on asset sales); (2) divided by $2,000,000. As of October 31, 2013, we were in compliance with our financial covenants.

Our credit facilities with United FCS are secured by substantially all our assets. There are no savings account balance collateral requirements as part of this credit facility.

In December 2011, the Company purchased a Shuttlewagon Railcar Mover for use at its facility. The Company financed the entire purchase price through Capital One Equipment Leasing and Finance. As of October 31, 2013, the loan balance was approximately $383,000. The note is on a five-year term at a fixed annual interest rate of 3.875%.

Heron Lake BioEnergy

Credit Arrangements with AgStar

HLBE entered into an amended and restated master loan agreement with AgStar Financial Services, PCA ("AgStar") under which it has two forms of debt as of October 31, 2013: a term note and a revolving term note. HLBE's total indebtedness to AgStar as of October 31, 2013 was approximately $22.6 million, consisting of approximately $16.6 million under the term note and approximately $6.0 million under the revolving term note.

HLBE's loan agreements with AgStar are secured by substantially all business assets and are subject to various financial and non-financial covenants that limit distributions and debt and require minimum debt service coverage, net worth, and working capital requirements. HLBE was in compliance with the covenants of its loan agreements with AgStar as of October 31, 2013. In the past, HLBE’s failure to comply with the covenants of the master loan agreement and failure to timely pay required installments of principal has resulted in events of default under the master loan agreement, entitling AgStar to accelerate and declare due all amounts outstanding under the master loan agreement. If AgStar accelerated and declared due all amounts outstanding under the master loan agreement, HLBE would not have adequate cash to repay the amounts due, resulting in a loss of control of its business or bankruptcy. There can be no assurance that HLBE will be able to maintain compliance with its agreements with AgStar. Upon an occurrence of an event of default or an event that will lead to HLBE's default, AgStar may upon notice terminate its commitment to loan funds and declare the entire unpaid principal balance of the loans, plus accrued interest, immediately due and payable. An event of default includes, but is not limited to, HLBE's failure to make payments when due, insolvency, any material adverse change in HLBE's financial condition or HLBE's breach of any of the covenants, representations or warranties we have given in connection with the transaction.

Term Note

With respect to the term loan, HLBE must make equal monthly payments of principal and interest on the term loan based on a 10-year amortization, provided the entire principal balance and accrued and unpaid interest on the term loan is due and payable in full on the maturity date of September 1, 2016. In addition, HLBE is required to make additional payments annually on debt

29

for up to 25% of the excess cash flow, as defined by the agreement, up to $2 million per year. Through September 1, 2014, the loan bears interest at 5.75% as long as HLBE is in compliance with its debt covenants. On September 1, 2014, the interest on the term loan will be adjusted to LIBOR plus 3.50%, but the total interest rate shall not be less than 5%.

Revolving Term Note

With respect to the revolving term loan, the loan matures in September 2016. Amounts borrowed by HLBE under the term revolving loan can be repaid and may be re-borrowed at any time prior to maturity date of the term revolving loan, provided that outstanding advances may not exceed the amount of the term revolving loan commitment. Amounts outstanding on the term revolving loan bear interest at a variable rate equal to the greater of a LIBOR rate plus 3.50% or 5.0%, payable monthly. At October 31, 2013, the revolving term loan carried an interest rate of 5.0%. HLBE also pays an unused commitment fee on the unused portion of the term revolving term loan commitment at the rate of 0.35% per annum, payable in arrears in quarterly installments during the term of the revolving term loan. At October 31, 2013, HLBE had $6.0 million outstanding under the revolving term loan and an additional $12.5 million was available. The amount available under the revolving term loan is reduced by $2 million at October 31 each year until September 2016, when the unpaid balance is due.

Subordinated Convertible Debt

On September 18, 2013, HLBE entered into an indenture with U.S. Bank National Association (“U.S. Bank”), as trustee and collateral agent, in connection with the closing of HLBE's offering of a maximum of $12 million aggregate principal amount of 7.25% Secured Subordinated Notes due 2018 (the “Notes”). On September 18, 2013, HLBE sold an aggregate principal amount of approximately $2.8 million of the Notes. Additionally, subscribers from HLBE's prior interim subordinated notes offering holding an aggregate principal amount of approximately $1.3 million of HLBE's interim subordinated notes elected to exchange their notes for Notes under the indenture, per the original terms of the interim subordinated notes. Therefore HLBE has an aggregate principal amount of approximately $4.1 million in Notes. The Notes are subordinated secured obligations, with interest payable on April 1 and October 1 of each year, beginning April 1, 2014, through the maturity date of October 1, 2018 at a rate of 7.25% per annum. The Notes are secured by a second mortgage and lien position on, among other assets, HLBE's property, plant and equipment located in Heron Lake, Minnesota, which mortgage and lien position are junior to and subordinated to HLBE's senior debt with AgStar. Beginning on October 1, 2014, and each anniversary date thereafter prior to the maturity date of the Notes, and on the maturity date of the Notes, and prior to the effective time of certain corporate actions, each holder of Notes has the right, at such holder’s option, to irrevocably convert all (but not less than all) of such holder’s Notes into HLBE's membership units at the rate of $0.30 of principal amount per unit. In addition to the anniversary and event conversion rights, prior to any prepayment date, each holder of Notes has the right, at such holder’s option, to irrevocably convert the principal amount to be prepaid into HLBE's membership units at the rate of $0.30 of principal amount per unit. Subject to this conversion right, HLBE may, by at least 45 days but not more than 60 days notice to the holders thereof, prepay the outstanding amount of the Notes in whole or in part with accrued interest to the date of such prepayment on the amount prepaid, without penalty or premium, provided that any prepayment of Notes must be done pro rata to all holders of Notes.

Other Credit Arrangements

In addition to HLBE's primary credit arrangement with AgStar and our subordinated convertible debt, HLBE has other material credit arrangements and debt obligations.

In October 2003, HLBE entered into an industrial water supply development and distribution agreement with the City of Heron Lake, Jackson County, and Minnesota Soybean Processors. In consideration of this agreement, HLBE and Minnesota Soybean Processors are allocated equally the debt service on $735,000 in water revenue bonds that were issued by the City to support this project that mature in February 2019. The parties have agreed that prior to the scheduled expiration of the agreement, they will negotiate in good faith to replace the agreement with a further agreement regarding the wells and related facilities. In May 2006, HLBE entered into an industrial water supply treatment agreement with the City of Heron Lake and Jackson County. Under this agreement, HLBE pays monthly installments over 24 months starting January 1, 2007 equal to one years' debt service on approximately $3.6 million in water revenue bonds, which will be returned to HLBE if any funds remain after final payment in full on the bonds and assuming HLBE complies with all payment obligations under the agreement. As of October 31, 2013 and 2012, there was a total of $2.6 million and $2.9 million in outstanding water revenue bonds, respectively. HLBE classifies its obligations under these bonds as assessments payable. The interest rates on the bonds range from 0.50% to 8.73%.

In November 2007, HLBE entered into a shared savings contract with Interstate Power and Light Company ("IPL"), its electrical service provider. Under the agreement, IPL is required to pay $1,850,000 to fund project costs for the purchase and installation of electrical equipment. In exchange, HLBE is required to share a portion of the energy savings with IPL that may be derived from the decreased energy consumption from the new equipment. HLBE isrequired to pay IPL approximately $30,000

30

for the first thirteen billing cycles, $140,000 at the end of the thirteenth billing cycle, and thereafter, approximately $30,000 for the remainder of the billing cycles. These amounts represent IPL's portion of the shared savings. HLBE also granted IPL a security interest in the electrical equipment to be installed on its site. The shared savings contract expired December 31, 2012.

To fund the purchase of the distribution system and substation for the plant, HLBE entered into a loan agreement with Federated Rural Electric Association pursuant to which HLBE borrowed $600,000 by a secured promissory note. Under the note HLBE is required to make monthly payments to Federated Rural Electric Association of $6,250 consisting of principal and an annual fee of 1% beginning on October 10, 2009. In exchange for this loan, Federated Rural Electric Association was granted a security interest in the distribution system and substation for the plant. The balances of this loan at October 31, 2013 and 2012 were $298,750 and $368,750, respectively.

HLBE has a note payable in connection with the construction of its pipeline assets. This loan was initially due in December 2011, but was converted in February 2012 to a term loan with a three-year repayment period. The balances of this loan at October 31, 2013 and 2012 were $1,013,132 and $818,884, respectively. Interest on the loan is at 5.29%. The note is secured by the assets of Agrinatural Gas, LLC.

HLBE financed its corn oil separation equipment from the equipment vendor. HLBE pays approximately $40,000 per month on this debt, conditioned upon revenue generated from the corn oil separation equipment. The monthly payment includes implicit interest of 5.57% until maturity in May 2015. The note is secured by the corn oil separation equipment. The balances of this loan at October 31, 2013 and 2012 were $640,653 and $1,072,310, respectively.

HLBE also has a note payable to the minority owner of Agrinatural Gas, LLC in the amount of $300,000 at October 31, 2013. Interest on the note is 5.43% and the note has a maturity date in October 2014.

Contractual Obligations

The following table provides information regarding the contractual obligations of the Company as of October 31, 2013:

	Total		Less than One Year		One to Three Years		Three to Five Years		Greater Than Five Years
Long-Term Debt Obligations (1)	$	37,687,311	$	4,501,215	$	24,292,098	$	7,751,238	$	1,142,760
Operating Lease Obligations (2)	$	11,175,639	$	3,525,671	$	6,781,468	$	868,500	$	—
Total Contractual Obligations	$	48,862,950	$	8,026,886	$	31,073,566	$	8,619,738	$	1,142,760

(1) Long-term debt obligations include both principal and interest payments.

(2) Operating lease obligations include the Company's rail car lease (Note 7).

Off-Balance Sheet Arrangements.

We currently have no off-balance sheet arrangements.

ITEM 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

We are exposed to the impact of market fluctuations associated with interest rates and commodity prices as discussed below. We have no exposure to foreign currency risk as all of our business is conducted in U.S. Dollars. 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, ethanol and natural gas. 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 pursuant to the requirements of Generally Accepted Accounting Principles ("GAAP").

Interest Rate Risk

We are exposed to market risk from changes in interest rates. Exposure to interest rate risk results primarily from our credit facilities with United FCS, PCA and AgStar Financial Services, PCA. Specifically, we have $25,071,191 outstanding in variable rate debt as of October 31, 2013. The specifics of these credit facilities are discussed in greater detail in “Item 7 - Management's Discussion and Analysis of Financial Condition and Results of Operations - Indebtedness.”

31

Below is a sensitivity analysis we prepared regarding our income exposure to changes in interest rates. The sensitivity analysis below shows the anticipated effect on our income from a 10% adverse change in interest rates for a one-year period.

Outstanding Variable Rate Debt at October 31, 2013	Interest Rate at October 31, 2013		Interest Rate Following 10% Adverse Change		Annual Adverse Change to Income
$2,513,674	3.22	%	3.542	%	$8,119
$16,577,641	5.75	%	6.325	%	$95,321
$5,979,876	5.00	%	5.500	%	$29,899

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 distillers 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 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 corn prices move in reaction to market trends and information, our income statement will be affected depending on the impact such market movements have on the value of our derivative instruments. Depending on market movements, crop prospects and weather, these price protection positions may cause immediate adverse effects, but are expected to produce long-term positive growth for us.

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 spot prices of corn, natural gas, and ethanol as of October 31, 2013, 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 October 31, 2013. 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 as of October 31, 2013		Approximate Adverse Change to Income
Natural Gas	3,000,000	MMBTU	10	%	$	1,395,000
Ethanol	119,300,000	Gallons	10	%	$	21,474,000
Corn	40,750,000	Bushels	10	%	$	17,107,500

Participation in Captive Reinsurance Company

We participate in a captive reinsurance company (“Captive”). The Captive reinsures losses related to workman's compensation, commercial property and general liability. Premiums are accrued by a charge to income for the period to which the premium relates and is remitted by our insurer to the captive reinsurer. The Captive reinsures losses in excess of a predetermined amount. The Captive insurer has estimated and collected a premium amount in excess of expected losses but less than the aggregate loss limits reinsured by the Captive. We have contributed limited capital surplus to the Captive that is available to fund losses should the actual losses sustained exceed premium funding. So long as the Captive is fully-funded through premiums and capital contributions to the aggregate loss limits reinsured, and the fronting insurers are financially strong, we cannot be assessed over the amount of our current contributions.

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ITEM 8.    FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

Board of Governors

Granite Falls Energy, LLC and Subsidiaries

Granite Falls, Minnesota

We have audited the accompanying consolidated balance sheets of Granite Falls Energy, LLC and Subsidiaries as of October 31, 2013 and 2012, and the related consolidated statements of operations, changes in members’ equity, and cash flows for each of the years in the three-year period ended October 31, 2013. Granite Falls Energy, LLC’s management is responsible for these consolidated financial statements. Our responsibility is to express an opinion on these consolidated 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 consolidated 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 audit 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 consolidated 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 consolidated financial statements referred to above present fairly, in all material respects, the financial position of Granite Falls Energy, LLC and Subsidiaries as of October 31, 2013 and 2012, and the results of its operations and its cash flows for each of the years in the three-year period ended October 31, 2013 in conformity with accounting principles generally accepted in the United States of America.

	/s/ Boulay PLLP
	Certified Public Accountants
Minneapolis, Minnesota
January 29, 2014

33

GRANITE FALLS ENERGY, LLC AND SUBSIDIARIES

Consolidated Balance Sheets

ASSETS	October 31, 2013		October 31, 2012
Current Assets
Cash	$	1,158,774	$	685,828
Restricted cash	393,750		494,000
Accounts receivable	6,450,694		7,356,534
Inventory	12,370,277		12,013,169
Prepaid expenses and other current assets	1,096,483		165,519
Total current assets	21,469,978		20,715,050
Property, Plant and Equipment
Land and improvements	12,307,063		7,095,172
Railroad improvements	8,005,523		4,121,148
Process equipment and tanks	110,440,407		64,678,860
Administration building	1,015,361		279,734
Office equipment	265,792		154,072
Rolling stock	1,691,857		1,305,395
Construction in progress	2,067,213		3,831,263
	135,793,216		81,465,644
Less accumulated depreciation	46,984,361		41,047,562
Net property, plant and equipment	88,808,855		40,418,082
Goodwill	1,372,473		—
Other Assets	1,021,916		—
Total Assets	$	112,673,222	$	61,133,132

Notes to the Consolidated Financial Statements are an integral part of this Statement.

34

GRANITE FALLS ENERGY, LLC AND SUBSIDIARIES

Consolidated Balance Sheets

LIABILITIES AND MEMBERS' EQUITY	October 31, 2013		October 31, 2012
Current Liabilities
Current portion of long-term debt	$	3,490,808	$	114,718
Accounts payable	3,058,633		3,527,840
Corn payable to FCE	4,001,852		1,995,997
Commodity derivative instruments	75,113		45,563
Accrued liabilities	696,858		318,819
Total current liabilities	11,323,264		6,002,937
Long-Term Debt, less current portion	32,981,955		5,274,870
Commitments and Contingencies
Members' Equity
Members' equity attributable to Granite Falls Energy, LLC consists of 30,606 units authorized, issued, and outstanding	59,887,346		49,855,325
Noncontrolling interest	8,480,657		—
Total members' equity	68,368,003		49,855,325
Total Liabilities and Members' Equity	$	112,673,222	$	61,133,132

Notes to the Consolidated Financial Statements are an integral part of this Statement.

35

GRANITE FALLS ENERGY, LLC AND SUBSIDIARIES

Consolidated Statements of Operations

For the fiscal years ended,	October 31, 2013			October 31, 2012			October 31, 2011
Revenues	$	224,100,934		$	175,162,043		$	156,521,489
Cost of Goods Sold	210,077,621			172,708,074			142,353,416
Gross Profit	14,023,313			2,453,969			14,168,073
Operating Expenses	2,988,583			2,449,596			2,002,706
Operating Income	11,034,730			4,373			12,165,367
Other Income (Expense):
Other income (expense), net	(48,373		)	182,186			37,281
Interest income	813			18,050			93,566
Interest expense	(428,397		)	(44,002		)	(4,358		)
Total other income (expense), net	(475,957		)	156,234			126,489
Net Income	10,558,773			160,607			12,291,856
Net Income Attributable to Noncontrolling Interest	526,752			—			—
Net Income Attributable to Granite Falls Energy, LLC	$	10,032,021		$	160,607		$	12,291,856
Weighted Average Units Outstanding - Basic and Diluted	30,606			30,614			30,656
Amounts attributable to Granite Falls Energy, LLC
Net Income Per Unit - Basic and Diluted	$	327.78		$	5.25		$	400.96
Distributions Per Unit - Basic and Diluted	$	—		$	—		$	600.00

Notes to the Consolidated Financial Statements are an integral part of this Statement.

36

GRANITE FALLS ENERGY, LLC AND SUBSIDIARIES

Consolidated Statement of Changes in Members' Equity

	Members' Equity Attributable to Granite Falls Energy, LLC			Noncontrolling Interest			Total Members' Equity
Balance - October 31, 2010	$	55,862,882		$	—		$	55,862,882
Member distributions	(18,393,600		)	—			(18,393,600		)
Net income for the year ended October 31, 2011	12,291,856			—			12,291,856
Balance - October 31, 2011	49,761,138			—			49,761,138
Repurchase of 50 membership units in December 2011	(66,420		)	—			(66,420		)
Net income for the year ended October 31, 2012	160,607			—			160,607
Balance - October 31, 2012	49,855,325			—			49,855,325
Recognition of noncontrolling interest upon acquisition of business	—			7,159,741			7,159,741
Distribution attributable to noncontrolling interest	—			(38,336		)	(38,336		)
Issuance of subsidiary units attributable to noncontrolling interest	—			832,500			832,500
Net income attributable to noncontrolling interest	—			526,752			526,752
Net income attributable to Granite Falls Energy, LLC	10,032,021			—			10,032,021
Balance - October 31, 2013	$	59,887,346		8,480,657			68,368,003

Notes to the Consolidated Financial Statements are an integral part of this Statement.

37

GRANITE FALLS ENERGY, LLC AND SUBSIDIARIES

Consolidated Statements of Cash Flows

For the fiscal years ended,	October 31, 2013			October 31, 2012			October 31, 2011
Cash Flows from Operating Activities:
Net income	$	10,558,773		$	160,607		$	12,291,856
Adjustments to reconcile net income to net cash provided by (used in) operations:
Depreciation and amortization	5,549,204			4,161,021			3,988,606
Change in fair value of derivative instruments	(155,563		)	1,651,799			(1,271,242		)
Change in operating assets and liabilities:
Restricted cash	611,205			1,009,000			(601,500		)
Derivative instruments	185,113			(1,202,186		)	1,619,692
Accounts receivable	3,910,961			(3,578,987		)	(613,338		)
Inventory	1,946,049			(3,397,758		)	(4,284,741		)
Prepaid expenses and other current assets	176,061			12,274			(60,904		)
Accounts payable	(5,995		)	286,878			871,671
Accrued liabilities	(59,920		)	(56,606		)	(60,514		)
Net Cash Provided by (Used in) Operating Activities	22,715,888			(953,958		)	11,879,586
Cash Flows from Investing Activities:
Proceeds from maturity of short-term investments	—			—			3,500,000
Payments for capital expenditures	(2,636,048		)	(4,083,943		)	(3,550,020		)
Payments from sale of land	540,000			—			—
Payments for land acquisitions	—			(3,467,199		)	—
Payments for acquisition of Project Viking, net of cash acquired	(6,977,236		)	—			—
Net Cash Used in Investing Activities	(9,073,284		)	(7,551,142		)	(50,020		)
Cash Flows from Financing Activities:
Proceeds from long-term debt	—			5,490,926			—
Payments on long-term debt	(16,840,158		)	(101,338		)	(232,431		)
Proceeds from issuance of subsidiary convertible notes	3,670,500			—			—
Payments for membership unit redemption	—			(66,420		)	—
Member distributions paid	—			(9,196,800		)	(9,196,800		)
Net Cash Used in Financing Activities	(13,169,658		)	(3,873,632		)	(9,429,231		)
Net Increase (Decrease) in Cash	472,946			(12,378,732		)	2,400,335
Cash - Beginning of Period	685,828			13,064,560			10,664,225
Cash - End of Period	$	1,158,774		$	685,828		$	13,064,560
Supplemental Cash Flow Information
Cash paid during the period for:
Interest expense	$	388,306		$	44,002		$	6,857

Notes to the Consolidated Financial Statements are an integral part of this Statement.

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GRANITE FALLS ENERGY, LLC AND SUBSIDIARIES

Consolidated Statements of Cash Flows

For the fiscal years ended,	October 31, 2013		October 31, 2012		October 31, 2011
Supplemental Disclosure of Noncash Investing, Operating and Financing Activities
Conversion of subsidiary subordinated convertible notes	$	934,500	$	—	$	—
Distribution to non-controlling interest in accrued expenses	$	38,336	$	—	$	—
Member distributions included in distribution payable	$	—	$	—	$	9,196,800
Capital expenditures and construction in process included in accounts payable	$	605,750	$	1,129,000	$	—

Notes to the Consolidated Financial Statements are an integral part of this Statement.

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GRANITE FALLS ENERGY, LLC AND SUBSIDIARIES

Notes to Consolidated Financial Statements

October 31, 2013 and 2012

1. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

Principles of Consolidation

The accompanying consolidated financial statements consolidate the operating results and financial position of Granite Falls Energy, LLC (“GFE” or the “Company”), and its wholly owned subsidiary, Project Viking, L.L.C. ("Project Viking") which owns 60.8% of Heron Lake BioEnergy, LLC (“HLBE”). The remaining 39.2% ownership of HLBE is included in the consolidated financial statements as a non-controlling interest. All intercompany balances and transactions are eliminated in consolidation. The acquisition occurred on July 31, 2013 and therefore the consolidated statements of operations only include the three month period ended October 31, 2013 of HLBE. See Note 3 for details of acquisition.

Nature of Business

GFE is a Minnesota limited liability company currently producing fuel-grade ethanol, distillers grains, and crude corn oil near Granite Falls, Minnesota and sells these products, pursuant to marketing agreements, throughout the continental United States and on the international market. GFE's plant has an approximate annual production capacity of 60 million gallons, but is currently permitted to produce up to 70 million gallons of undenatured ethanol on a twelve month rolling sum basis.

HLBE is a Minnesota limited liability company currently producing fuel-grade ethanol, distillers grains, and crude corn oil near Heron Lake, Minnesota and sells these products, pursuant to marketing agreements, throughout the continental United States. HLBE's plant has an approximate annual production capacity of 55 million gallons, but is currently permitted to produce up to 59.2 million gallons.

Fiscal Reporting Period

The Company has adopted a fiscal year ending October 31 for financial reporting purposes.

Accounting Estimates

Management uses estimates and assumptions in preparing these financial statements in accordance with generally accepted accounting principles in the United States of America. 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. The Company uses estimates and assumptions in accounting for the following significant matters, among others: economic lives of property, plant, and equipment, valuation of commodity derivatives and inventory, and the assumptions used in the impairment analysis of long-lived assets and the assumptions used to estimate the fair value of acquired assets and liabilities, which includes goodwill. Actual results may differ from previously estimated amounts, and such differences may be material to our financial statements. The Company periodically reviews estimates and assumptions, and the effects of revisions are reflected in the period in which the revision is made.

Cash

The Company maintains its accounts primarily at two financial institutions, of which one is a member of the Company. At times throughout the year, the Company's cash balances may exceed amounts insured by the Federal Deposit Insurance Corporation. The Company does not believe it is exposed to any significant credit risk on its cash balances.

Restricted Cash

The Company has restricted cash balances relating to its margin requirements with the Company's commodity derivative broker based on open commodity contracts discussed in Note 5.

Accounts Receivable

Credit terms are extended to customers in the normal course of business. The Company performs ongoing credit evaluations of its customers' financial condition and, generally, requires no collateral.

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GRANITE FALLS ENERGY, LLC AND SUBSIDIARIES

Notes to Consolidated Financial Statements

October 31, 2013 and 2012

Accounts receivable are recorded at their estimated net realizable value. Accounts are considered past due if payment is not made on a timely basis in accordance with the Company's credit terms. Accounts considered uncollectible are written off. The Company follows a policy of providing an allowance for doubtful accounts; however, based on historical experience, and its evaluation of the current status of receivables, the Company is of the belief that such accounts will be collectible in all material respects and thus an allowance was not necessary at October 31, 2013 or 2012. It is at least possible this estimate will change in the future.

Inventory

Inventory is stated at the lower of cost or market. Cost for all inventories is determined using the first in first out method (FIFO). Market is based on current replacement values except that it does not exceed net realizable values and it is not less than net realizable values reduced by allowances from normal profit margin. Inventory consists of raw materials, work in process, finished goods, and spare parts. Corn is the primary raw material along with other raw materials. Finished goods consist of ethanol, distillers grains, and corn oil.

Property, Plant, and Equipment

Property, plant, and equipment are stated at cost. Depreciation is provided over the following estimated useful lives by use of the straight-line method.

Asset Description	Years
Land improvements	5-20 years
Buildings	10-30 years
Grain handling equipment	5-15 years
Mechanical equipment	5-15 years
Equipment	5-10 years

Maintenance and repairs are expensed as incurred; major improvements and betterments are capitalized.  Construction in progress expenditures will be depreciated using the straight-line method over their estimated useful lives once the assets are placed into service. Depreciation expense totaled approximately $5,937,000, $4,161,000, and $3,979,000 for the fiscal years ended October 31, 2013, 2012, and 2011, respectively.

Long-Lived Assets

Long-lived assets, such as property, plant, and equipment, and purchased intangible assets subject to amortization, are reviewed for impairment whenever events or changes in circumstances indicate that the carrying amount of an asset may not be recoverable. If circumstances require a long-lived asset be tested for possible impairment, the Company first compares undiscounted cash flows expected to be generated by an asset to the carrying value of the asset. If the carrying value of the long-lived asset is not recoverable on an undiscounted cash flow basis, impairment is recognized to the extent that the carrying value exceeds its fair value. Fair value is determined through various valuation techniques including, but not limited to, discounted cash flow models, quoted market values and third-party independent appraisals, as considered necessary. No indicators of impairment existed during fiscal 2013 or 2012 that would have triggered impairment testing, and therefore, no impairment expense was recorded during 2013 or 2012.

Revenue Recognition

The Company generally sells ethanol and related products pursuant to marketing agreements. Revenues from the production of ethanol and the related products are recorded when the customer has taken title and assumed the risks and rewards of ownership, prices are fixed or determinable and collectability is reasonably assured. Ethanol and related products are generally shipped free on board (FOB) shipping point. The Company believes there are no ethanol sales, during any given month, which should be considered contingent and recorded as deferred revenue.

In accordance with the Company's agreements for the marketing and sale of ethanol and related products, marketing fees and commissions due to the marketers are deducted from the gross sales price as earned. These fees and commissions are recorded net of revenues, as they do not provide an identifiable benefit that is sufficiently separable from the sale of ethanol and related

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GRANITE FALLS ENERGY, LLC AND SUBSIDIARIES

Notes to Consolidated Financial Statements

October 31, 2013 and 2012

products. Shipping costs paid by the Company to the marketer in the sale of ethanol are not specifically identifiable and, as a result, are recorded based on the net selling price reported to the Company from the marketer. Shipping costs incurred by the Company in the sale of distillers grains and corn oil are included in cost of goods sold.

Fair Value of Financial Instruments

The Company's accounting for fair value measurements of assets and liabilities that are recognized or disclosed at fair value in the financial statements on a recurring or nonrecurring basis adhere to the Financial Accounting Standards Board (FASB) fair value hierarchy that prioritizes the inputs to valuation techniques used to measure fair value. The Company has adopted guidance for fair value measurement related to nonfinancial items that are recognized and disclosed at fair value in the financial statements on a nonrecurring basis. The guidance establishes a fair value hierarchy that prioritizes the inputs to valuation techniques used to measure fair value. The hierarchy gives the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities (Level 1 measurements) and the lowest priority to measurements involving significant unobservable inputs (Level 3 measurements).

The three levels of the fair value hierarchy are as follows:

• Level 1 inputs are quoted prices (unadjusted) in active markets for identical assets or liabilities that the Company has the ability to access at the measurement date.

• Level 2 inputs are inputs other than quoted prices included within Level 1 that are observable for the asset or liability, either directly or indirectly, for substantially the full term of the asset or liability.

• Level 3 inputs are unobservable inputs for the asset or liability.

The level in the fair value hierarchy within which a fair measurement in its entirety falls is based on the lowest level input that is significant to the fair value measurement in its entirety.

Except for those assets and liabilities which are required by authoritative accounting guidance to be recorded at fair value in our balance sheets, the Company has elected not to record any other assets or liabilities at fair value. No events occurred during the fiscal years ended October 31, 2013 or 2012 that required adjustment to the recognized balances of assets or liabilities, which are recorded at fair value on a nonrecurring basis.

The carrying value of cash, restricted cash, accounts receivable, accounts payable and accrued liabilities approximates fair value due to the short maturity of these instruments. The Company obtains fair value measurements from an independent pricing service for corn derivative contracts.  The fair value measurements consider observable data that may include dealer quotes and live trading levels from the Chicago Board of Trade and New York Mercantile Exchange markets. The fair value of the long-term debt is estimated based on anticipated interest rates which management believes would currently be available to the Company for similar issues of debt, taking into account the current credit risk of the Company and other market factors. The Company believes the carrying value of the debt instruments approximate fair value.

Derivative Instruments

From time to time the Company enters into derivative transactions to hedge its exposures to commodity price fluctuations. The Company is required to record these derivatives in the balance sheets at fair value.

In order for a derivative to qualify as a hedge, specific criteria must be met and appropriate documentation maintained. Gains and losses from derivatives that do not qualify as hedges, or are undesignated, must be recognized immediately in earnings. If the derivative does qualify as a hedge, depending on the nature of the hedge, changes in the fair value of the derivative will be either offset against the change in fair value of the hedged assets, liabilities, or firm commitments through earnings or recognized in other comprehensive income until the hedged item is recognized in earnings. Changes in the fair value of undesignated derivatives are recorded in earnings.

Additionally, the Company is required to evaluate its contracts to determine whether the contracts are derivatives. Certain contracts that literally meet the definition of a derivative may be exempted as “normal purchases or normal sales”. Normal purchases and

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GRANITE FALLS ENERGY, LLC AND SUBSIDIARIES

Notes to Consolidated Financial Statements

October 31, 2013 and 2012

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 accounting and reporting requirements, and therefore, are not marked to market in our financial statements.

In order to reduce the risks caused by market fluctuations, the Company occasionally hedges its anticipated corn, natural gas, and denaturant purchases and ethanol sales by entering into options and futures contracts. These contracts are used with the intention to fix the purchase price of anticipated requirements for corn in the Company's ethanol production activities and the related sales price of ethanol. The fair value of these contracts is based on quoted prices in active exchange-traded or over-the-counter market conditions. Although the Company believes its commodity derivative positions are economic hedges, none have been formally designated as a hedge for accounting purposes and derivative positions are recorded on the balance sheet at their fair market value, with changes in fair value recognized in current period earnings or losses. The Company does not enter into financial instruments for trading or speculative purposes.

The Company has adopted authoritative guidance related to “Derivatives and Hedging,” and has included the required enhanced quantitative and qualitative disclosure about objectives and strategies for using derivatives, quantitative disclosures about fair value amounts of gains and losses from derivative instruments, and disclosures about credit-risk-related contingent features in derivative agreements. See further discussion in Note 5.

Income Taxes

The Company is treated as a partnership for federal and state income tax purposes, and generally does not incur income taxes. Instead its earnings and losses are included in the income tax returns of its members. Therefore, no provision or liability for federal or state income taxes has been included in these financial statements. The Company had no significant uncertain tax positions as of October 31, 2013 or 2012. For years before fiscal 2011, the Company is no longer subject to U.S. Federal or state income tax examinations.

Environmental Liabilities

The Company's operations are subject to environmental laws and regulations adopted by various governmental entities 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 location. 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 liability is probable and the costs can be reasonably estimated. No expense has been recorded for the fiscal years ended October 31, 2013, 2012, or 2011.

Net Income per Unit

Basic net income per unit is computed by dividing net income by the weighted average number of members' units outstanding during the period. 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, for all periods presented, the calculations of the Company's basic and diluted net income per unit are the same.

Business Combinations

The Company allocates the total purchase price of a business combination to the assets acquired and the liabilities assumed based on their estimated fair values at the acquisition date, with the excess purchase price recorded as goodwill. The Company used current market data to assist them in determining the fair value of the assets acquired and liabilities assumed, including goodwill, based on recognized business valuation methodology. Subsequent to the acquisition but not to exceed one year from the acquisition date, the Company will record any material adjustments retrospectively to the initial estimate based on new information obtained about facts and circumstances that existed as of the acquisition date. The Company expenses any acquisition-related costs as incurred in connection with business combinations. An income, market or cost valuation method may be utilized to estimate the

43

GRANITE FALLS ENERGY, LLC AND SUBSIDIARIES

Notes to Consolidated Financial Statements

October 31, 2013 and 2012

fair value of the assets acquired or liabilities assumed in a business combination. The income valuation method represents the present value of future cash flows over the life of the asset using (i) discrete financial forecasts, which rely on management's estimates of revenue and operating expenses, (ii) long-term growth rates, and (iii) an appropriate discount rate. The market valuation method uses prices paid for a reasonably similar asset by other purchasers in the market, with adjustments relating to any differences between the assets. The cost valuation method is based on the replacement cost of a comparable asset at prices at the time of the acquisition reduced for depreciation of the asset.

Goodwill

Goodwill represents the cost in excess of the fair value of net assets acquired. The Company conducts impairment assessments annually or when events indicate a triggering event has occurred.

2. RISKS AND UNCERTAINTIES

The Company has certain risks and uncertainties that it experiences during volatile market conditions. These volatilities can have a severe impact on operations.  The Company's revenues are derived from the sale and distribution of ethanol, distillers grains, and corn oil to customers primarily located in the United States. Corn for the production process is supplied to our plant primarily from local agricultural producers and from purchases on the open market.  Ethanol sales typically average 80-85% of total revenues and corn costs typically average 70-80% of cost of goods sold.

The Company's operating and financial performance is largely driven by the prices at which they sell ethanol and the net expense of corn. The price of ethanol is influenced by factors such as supply and demand, the weather, government policies and programs, and unleaded gasoline prices and the petroleum markets as a whole. Excess ethanol supply in the market, in particular, puts downward pressure on the price of ethanol. Our largest cost of production is corn.  The cost of corn is generally impacted by factors such as supply and demand, the weather, government policies and programs, and our risk management program used to protect against the price volatility of these commodities.

3. BUSINESS COMBINATION

On July 31, 2013, the Company acquired 63.3% of the outstanding membership units of Heron Lake BioEnergy, LLC (“HLBE”) through its purchase of 100% of the membership units of Project Viking, L.L.C. (“Project Viking”), for a total purchase price of $17,024,500. HLBE is a 50 million gallon per year ethanol plant located in Heron Lake, Minnesota. Project Viking was formed by the previous investor to only hold equity interests in HLBE and the debt incurred to obtain those interests and did not have any other assets or liabilities. The previous owner of Project Viking also owned approximately 12.82% of the outstanding membership units of the Company at July 31, 2013.

Immediately following the closing, the Company, through its 100% ownership of Project Viking, owned 24,080,949 Class A units and 15,000,000 Class B units of HLBE, for a total of 39,080,949 units, or 63.3% of the 61,697,104 outstanding units. As a result, under HLBE's member control agreement, Project Viking is entitled to appoint five (5) of the nine (9) governors to HLBE's board of governors.

On July 31, 2013, the Company entered into a Management Services Agreement with HLBE. Under the Management Services Agreement, the Company agreed to supply its own personnel to act as part-time officers and managers of HLBE for the positions of Chief Executive Officer, Chief Financial Officer, and Commodity Risk Manager. The initial term of the Management Services Agreement is three years. The Company will be paid $35,000 per month by HLBE for the first year of the Management Services Agreement. During years two and three of the agreement, HLBE agreed to pay the Company 50% of the total salary, bonuses, and other expenses and costs incurred by the Company for the three management positions. At the expiration of the initial term, the Management Services Agreement will automatically renew for successive one-year terms unless and until the Company or HLBE gives the other party 90-days written notice of termination prior to expiration of the initial term or the start of a renewal term.

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GRANITE FALLS ENERGY, LLC AND SUBSIDIARIES

Notes to Consolidated Financial Statements

October 31, 2013 and 2012

The acquisition date fair value of the consideration transferred consisted of the following:

Cash	$	8,000,000
Note payable	4,024,500
Assumption of note payable to Granite Falls Bank	5,000,000
Total Consideration	$	17,024,500

The assets and liabilities of Project Viking were recorded at their respective estimated fair values as of the date of the acquisition using generally accepted accounting principles for business combinations. The Company used a combination of the market and cost approaches that included unobservable level 3 inputs, to estimate the fair values of the assets acquired and liabilities assumed. The fair value of the long-term debt acquired was determined based on the present value of future contractual cash flows discounted at an interest rate that reflects the current borrowing rates available to the Company for loans with similar terms. The fair market value of the debt assumed was approximately $36.5 million and resulted in a debt premium balance of approximately $2.3 million being recorded as of the acquisition date. The debt premium is amortized as a reduction of interest expense over the term of the debt using the effective interest method. The value of the 36.66% noncontrolling interest was determined by using the fair value method by using the most recent arms-length transaction of HLBE's units that did not include a control premium. The goodwill is attributable to the synergies expected to arise after the acquisition in the purchasing of inputs and the sale of outputs.  Goodwill is not expected to be deductible for tax purposes.  The fair value of the assets acquired includes account receivables of approximately $3,107,000, all of which are expected to be collectible.

Subsequent to the initial purchase price allocation and within the one year measurement period, new information was obtained about facts and circumstances that existed as of the acquisition date. As such, the purchase price allocation of the HLBE acquisition was retroactively adjusted to include the effect of this measurement period adjustment.  An adjustment of approximately $273k was recorded to adjust the fair value of a noncontrolling interest in HLBE, which was adjusted through goodwill during the fourth quarter ended October 31, 2013. The retroactively adjusted purchase price allocation is as follows:

Cash	$	1,022,764
Restricted cash	510,955
Accounts receivable	3,107,121
Inventory	2,303,157
Prepaid expenses	1,107,025
Property, plant, and equipment	51,625,774
Other assets	924,252
Goodwill	1,372,473
Total assets acquired	$	61,973,521
Accounts payable	$	(936,893	)
Accrued expenses	(399,623		)
Notes payable	(36,452,764		)
Non-controlling interest	(7,159,741		)
Net purchase price	$	17,024,500

The acquisition occurred on the last day of the Company's fiscal third quarter, therefore the Company consolidated three months of HLBE's revenues and expenses in the consolidated statements of operations. HLBE contributed revenues of $38,560,522 and earnings of $1,305,044 to the Company for the three month period from August 1, 2013 to October 31, 2013. The net income attributable to non-controlling interests for the year ended October 31, 2013 totaled approximately $527,000.

The following represents the unaudited pro forma consolidated statement of operations as if the transaction occurred at the beginning of the following periods:

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GRANITE FALLS ENERGY, LLC AND SUBSIDIARIES

Notes to Consolidated Financial Statements

October 31, 2013 and 2012

	For the years ended
	October 31, 2013		October 31, 2012			October 31, 2011
	Unaudited		Unaudited			Unaudited
Revenues	$	349,304,556	$	343,821,978		$	320,641,864
Net income, including portion attributable to non-controlling interest of $712,289, ($20,702,684), and $361,351, respectively	$	4,864,820	$	(31,794,779	)	$	13,612,987
Earnings per share (30,606, 30,614, and 30,656 weighted average units outstanding - basic and diluted, respectively)	$	116.16	$	(617.00	)	$	412.75

The pro forma financial information is presented for informational purposes only and is not indicative of the results of operations that would have been achieved if the acquisition had taken place at the beginning of each of the periods presented. These amounts have been calculated after adjusting the results of HLBE to reflect the additional amortization of the debt premium that would have occurred assuming the fair value adjustment to long-term debt had been applied at the beginning of each period presented.

4. INVENTORY

Inventories consist of the following:

	October 31, 2013		October 31, 2012
Raw materials	$	4,652,465	$	8,977,820
Spare parts	1,636,466		584,011
Work in process	1,643,574		1,150,239
Finished goods	4,437,772		1,557,546
Totals	$	12,370,277	$	12,013,169

The Company performs a lower of cost or market analysis on inventory to determine if the market values of certain inventories are less than their carrying value, which is attributable primarily to decreases in market prices of corn and ethanol. Based on the lower of cost or market analysis, the Company did not record a lower of cost or market charge on certain inventories for the fiscal years ended October 31, 2013 or 2011. The Company recorded a lower of cost or market charge on certain inventories for the fiscal year ended October 31, 2012 for approximately $77,000.

5.    DERIVATIVE INSTRUMENTS

As of October 31, 2013, the total notional amount of the Company's outstanding corn derivative instruments was approximately 1,125,000 bushels that were entered into to hedge forecasted corn purchases through December 2013. There may be offsetting positions that are not shown on a net basis that could lower the notional amount of positions outstanding as disclosed above.

The following tables provide details regarding the Company's derivative instruments at October 31, 2013, none of which were designated as hedging instruments:

	Balance Sheet location	Assets		Liabilities
Corn contracts	Commodity derivative instruments	$	—	$	(75,113	)
Totals		$	—	$	(75,113	)

In addition, as of October 31, 2013 the Company maintained $393,750 of restricted cash related to margin requirements for the Company's commodity derivative instrument positions.

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GRANITE FALLS ENERGY, LLC AND SUBSIDIARIES

Notes to Consolidated Financial Statements

October 31, 2013 and 2012

As of October 31, 2012, the total notional amount of the Company's outstanding corn derivative instruments was approximately 1,235,000 bushels that were entered into to hedge forecasted corn purchases through March 2013. There may be offsetting positions that are not shown on a net basis that could lower the notional amount of positions outstanding as disclosed above.

The following tables provide details regarding the Company's derivative instruments at October 31, 2012, none of which were designated as hedging instruments:

	Balance Sheet location	Assets		Liabilities
Corn contracts	Commodity derivative instruments	$	—	$	(45,563	)
Totals		$	—	$	(45,563	)

In addition, as of October 31, 2012 the Company maintained approximately $494,000 of restricted cash related to margin requirements for the Company's derivative instrument positions.

The following tables provide details regarding the gains and (losses) from Company's derivative instruments in statements of operations, none of which are designated as hedging instruments:

	Statement of	Fiscal Years Ended October 31,
	Operations location	2013		2012			2011
Ethanol contracts	Revenue	$	—	$	—		$	(4,626	)
Corn contracts	Cost of Goods Sold	155,563		(1,651,799		)	1,280,413
Natural gas contracts	Cost of Goods Sold	—		—			(4,545		)
Total gain (loss)		$	155,563	$	(1,651,799	)	$	1,271,242

6.    DEBT FACILITIES

Granite Falls Energy:

GFE has two credit facilities with a lender. The first is a seasonal revolving operating loan facility in the amount of $5,660,000. The second is a revolving term loan facility in the amount of $18,000,000. However, the amount available for borrowing under this facility reduces by $2,000,000 semi-annually beginning September 1, 2014, with final payment due March 1, 2018.

The interest rates for both facilities are based on the bank's "One Month LIBOR Index Rate," plus 2.8% and 3.05% on the seasonal and revolving term commitments, respectively. The facilities are available through March 31, 2017 and March 31, 2018, respectfully. The outstanding balance on the revolving term loan on October 31, 2013 and October 31, 2012 was $2,513,674 and $4,891,952, respectively. GFE currently has no outstanding balance on the seasonal revolving operating loan facility.

The credit facilities require GFE to comply with certain financial covenants. As of October 31, 2013 and October 31, 2012, GFE was in compliance with these financial covenants and expects to be in compliance throughout fiscal 2014.

The credit facilities are secured by substantially all assets of the Company. There are no savings account balance collateral requirements as part of this credit facility.

At October 31, 2013, GFE also had letters of credit totaling $337,928 with the bank as part of a credit requirement of Northern Natural Gas. These letters of credit were reduced by $49,000 in November 2013.

As part of the acquisition of Project Viking discussed in Note 3, GFE assumed a note payable with Granite Falls Bank with a principal amount of $5,000,000. This note was paid in full on August 19, 2013.

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GRANITE FALLS ENERGY, LLC AND SUBSIDIARIES

Notes to Consolidated Financial Statements

October 31, 2013 and 2012

Also, as part of the acquisition of Project Viking discussed in Note 3, GFE issued a note payable to the previous owners of Project Viking with a principal amount of $4,024,500. The note matured on August 30, 2013 and interest accrued on the note at a rate of 4% per annum. This note was paid in full on August 26, 2013.

Heron Lake BioEnergy:

Term Note Payable

On May 17, 2013, HLBE renegotiated its term loan with AgStar in the amount of $17,400,000.  HLBE must make equal monthly payments of principal and interest on the term loan based on a 10-year amortization, provided the entire principal balance and accrued and unpaid interest on the term loan is due and payable in full on the maturity date of September 1, 2016.  In addition, HLBE is required to make additional payments annually on debt for up to 25%of the excess cash flow, as defined by the agreement, up to $2,000,000 per year.  Through September 1, 2014, the loan bears interest at 5.75% as long as HLBE is in compliance with their debt covenants.

On September 1, 2014, the interest term loan will be adjusted to LIBOR plus 3.50% but not less than 5%.  The loan agreements are secured by substantially all business assets and are subject to various financial and non-financial covenants that limit distributions and debt and require minimum debt service coverage, net worth, and working capital requirements.  HLBE was in compliance with the covenants of its master loan agreement with AgStar as of October 31, 2013.

Revolving Term Note

HLBE also obtained a three-year term revolving loan commitment in the amount of $20,500,000, under which AgStar agreed to make periodic advances to HLBE up to this original amount until September 1, 2016. Amounts borrowed by HLBE under the term revolving loan and repaid or prepaid may be re-borrowed at any time prior to maturity date of the term revolving loan, provided that outstanding advances may not exceed the amount of the term revolving loan commitment. Amounts outstanding on the term revolving loan bear interest at a variable rate equal to the greater of a LIBOR rate plus 3.50% or 5.0%, payable monthly. HLBE also pays an unused commitment fee on the unused portion of the term revolving loan commitment at the rate of 0.35% per annum, payable in arrears in quarterly installments during the term of the term revolving loan. Under the terms of the new agreement, the term revolving loan commitment is scheduled to decline by $2,000,000 annually, beginning on October 31, 2013 and each anniversary date thereafter. The maturity date of the term revolving loan is September 1, 2016.

Subordinated Convertible Debt

On May 17, 2013, HLBE’s previous Board of Governors loaned the Company approximately $1,400,000 as part of the convertible secured debt offering. An additional $3,700,000 was raised as part of a convertible debt offering during September 2013. The convertible secured debt is subordinated to the AgStar debt. The notes bear interest at 7.25% and are due in May 2018. On October 1, 2014, or immediately prior to the sale of all or effectively all of HLBE assets, each note is convertible to Class A stock at a rate of $0.30 per Class A unit. HLBE reserves the right to issue Class B units upon conversion if the principal balance of the convertible debt exceeds the authorized Class A units at the conversion rate. At the issuance, each debt holder had the option to convert to Class A units. As a result, holders elected to convert $934,500 in September for 3,115,000 Class A units.

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GRANITE FALLS ENERGY, LLC AND SUBSIDIARIES

Notes to Consolidated Financial Statements

October 31, 2013 and 2012

Long-term debt consists of the following:

	October 31, 2013		October 31, 2012
GRANITE FALLS ENERGY:
Capital One Shuttlewagon Railcar Mover (5 year term at 3.875%, due in monthly installments of $10,995)	$	382,918	$	497,636
Revolving Term Loan	2,513,674		4,891,952
HERON LAKE BIOENERGY:
Term note payable to lending institution (including premium of approximately $1.74m)	18,317,800		—
Revolving term note payable to lending institution (including premium of approximately $283k)	6,263,158		—
Assessment payable as part of water treatment agreement, due in semi-annual installments of $189,393 with interest at 6.55%, enforceable by statutory lien, with the final payment due in 2021. The Company made deposits for one years' worth of debt service payments that are held on deposit to be applied with the final payments of the assessment.	2,246,771		—
Assessment payable as part of water treatment agreement, due in semi-annual installments of $25,692 with interest at 0.50%, enforceable by statutory lien, with the final payment due in 2016.	152,698		—
Assessment payable as part of water supply agreement, due in monthly installments of $3,942 with interest at 8.73%, enforceable by statutory lien, with the final payment due in 2019.	205,209		—
Note payable to electrical company with monthly payments of $6,250 with a 1% maintenance fee due each October, due September 2017. The electrical company is a member of the Company.	293,750		—
Note payable to a lending institution for the construction of the pipeline assets initially due in December 2011, converted in February 2012 to a term loan with a three year repayment period. Interest is at 5.29% and the note, along with the line of credit in Note 8, is secured by substantially all assets of Agrinatural.	1,013,132		—
Note payable to noncontrolling interest member of Agrinatural. Interest is at 5.425%, with a maturity date of October 2014.	300,000		—
Equipment payable on corn oil separation equipment from a vendor. The Company pays approximately $40,000 per month conditioned upon revenue generated from the corn oil equipment. The monthly payment includes implicit interest of 5.57% until maturity in May 2015 and the note is secured by the equipment.	640,653		—
Subordinated Convertible Debt with interest of 7.25% paid on a semi-annual basis.	4,143,000		—
Totals	36,472,763		5,389,588
Less amounts due within one year	3,490,808		114,718
Net long-term debt	$	32,981,955	$	5,274,870

49

GRANITE FALLS ENERGY, LLC AND SUBSIDIARIES

Notes to Consolidated Financial Statements

October 31, 2013 and 2012

Estimated maturities of long-term debt at October 31, 2013 are as follows: 

2014	$	3,490,808
2015	2,846,762
2016	21,602,578
2017	522,563
2018	7,022,813
After 2018	987,239
Total long-term debt	$	36,472,763

7. LEASES

GFE has a lease agreement with a leasing company for 75 hopper cars to assist with the transport of distiller's grains by rail. In November 2010, the original lease was renewed for an additional five-year period. Based on final manufacturing and interest costs, the Company will pay the leasing company $620 per month plus $0.03 per mile traveled in excess of 36,000 miles per year. Rent expense for these leases was $557,000, $552,000 and $553,000 for the fiscal years ended October 31, 2013, 2012 and 2011, respectively.

GFE has lease agreements with three leasing companies for 176 rail car leases for the transportation of the Company's ethanol with various maturity dates through October 2017. The rail car lease payments are due monthly in the aggregate amount of approximately $121,000. Rent expense for these leases was $1,437,000, $1,278,000 and $1,171,000 for the fiscal years ended October 31, 2013, 2012 and 2011, respectively.

HLBE leases equipment, primarily rail cars, under operating leases through 2017. Rent expense for fiscal 2013, 2012, and 2011 was approximately $1,800,000, $2,200,000, and $1,800,000, respectively.

At October 31, 2013, the Company had the following commitments for payments of rentals under operating leases which at inception had a non-cancelable term of more than one year:

November 1, 2013 to October 31, 2014	$	2,602,286
November 1, 2014 to October 31, 2015	1,640,775
November 1, 2015 to October 31, 2016	940,910
November 1, 2016 to October 31, 2017	474,004
November 1, 2017 to October 31, 2018	60,816
Total minimum lease commitments	$	5,718,791

8. FAIR VALUE

The following table provides information on those derivative assets measured at fair value on a recurring basis at October 31, 2013:

	Carrying Amount in Balance Sheet October 31, 2013			Fair Value October 31, 2013			Fair Value Measurement Using
							Quoted Prices in Active Markets (Level 1)			Significant Other Observable Inputs (Level 2)		Significant unobservable inputs (Level 3)
Financial Liabilities:
Derivative Instruments	$	(75,113	)	$	(75,113	)	$	(75,113	)	$	—	$	—

50

GRANITE FALLS ENERGY, LLC AND SUBSIDIARIES

Notes to Consolidated Financial Statements

October 31, 2013 and 2012

The following table provides information on those derivative assets measured at fair value on a recurring basis at October 31, 2012:

	Carrying Amount in Balance Sheet October 31, 2012			Fair Value October 31, 2012			Fair Value Measurement Using
							Quoted Prices in Active Markets (Level 1)			Significant Other Observable Inputs (Level 2)		Significant unobservable inputs (Level 3)
Financial Liabilities:
Derivative Instruments	$	(45,563	)	$	(45,563	)	$	(45,563	)	$	—	$	—

We determine the fair value of commodity derivative instruments by obtaining 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 Chicago Board of Trade market and New York Mercantile Exchange.

9. MEMBERS' EQUITY

The Company has one class of membership units. The units have no par value and have identical rights, obligations and privileges. Income and losses are allocated to all members based upon their respective percentage of units held. As of October 31, 2013, 2012 and 2011, the Company had 30,606, 30,606 and 30,656 membership units authorized, issued, and outstanding, respectfully.

Subsequent to year end, in December 2013, the Board of Governors declared a cash distribution of $180 per unit or $5,509,080 for unit holders of record as of December 19, 2013. The distribution was paid on December 31, 2013.

In December 2011, the Board of Governors exercised its discretion to redeem 50 membership units totaling $66,420 from an investor due to a unique restriction on transfers situation.

In October 2011, the Board of Governors declared a cash distribution of $300 per unit or $9,196,800 for unit holders of record as of October 27, 2011. The distribution was paid on December 15, 2011.

In November 2010, the Board of Governors declared a cash distribution of $300 per unit or $9,196,800 for unit holders of record as of November 23, 2010. The distribution was paid on December 15, 2010.

10. EMPLOYEE BENEFIT PLANS

The Company has a defined contribution plan available to all of its qualified employees. The Company contributes a match of 50% of the participant's salary deferral up to a maximum of 3% of the employee's salary. Company contributions totaled approximately $50,000, $51,000, and $46,000 for the fiscal years ended October 31, 2013, 2012, and 2011, respectively.

51

GRANITE FALLS ENERGY, LLC AND SUBSIDIARIES

Notes to Consolidated Financial Statements

October 31, 2013 and 2012

11. INCOME TAXES

The differences between the financial statement basis and tax basis of assets are based on the following:

	October 31, 2013			October 31, 2012
Financial statement basis of assets	$	112,673,222		$	61,133,132
Organization & start-up costs capitalized for tax purposes, net	625,720			715,109
Tax depreciation greater than book depreciation	(24,977,852		)	(25,653,678		)
Unrealized derivatives losses	75,113			45,563
Capitalized inventory	35,761			10,957
Net effect of consolidation of acquired subsidiary	(10,396,697		)	—
Income tax basis of assets	$	78,035,267		$	36,251,083
Financial statement basis of liabilities	$	44,305,219		$	11,277,807
Debt premium - acquisition fair value adjustment	(2,023,441		)	—
Income tax basis of liabilities	$	42,281,778		$	11,277,807

There were no material differences between the financial statement basis and tax basis of the Company's liabilities.

12. COMMITMENTS AND CONTINGENCIES

Corn Storage and Grain Handling Agreement and Purchase Commitments

GFE has a corn storage and grain handling agreement with Farmers Cooperative Elevator (FCE), a member. Under the agreement, the Company agrees to purchase all of the corn needed for the operation of the plant FCE. The price of the corn purchased will be the bid price FCE establishes for the plant plus a set fee of per bushel.

At October 31, 2013, GFE had basis contracts for forward corn purchase commitments with FCE for 350,000 bushels for delivery in November 2013. At October 31, 2013, the Company also had 550,000 bushels of stored corn totaling approximately $2,346,000 with FCE that is included in inventory.

The Company purchased approximately $153,216,000 of corn from the member during fiscal 2013, of which approximately $4,002,000 is included in corn payable at October 31, 2013. The Company purchased approximately $148,289,000 of corn from the member during fiscal 2012, of which approximately $1,996,000 is included in corn payable at October 31, 2012. The Company purchased approximately $123,676,000 of corn from the member during fiscal 2011.

Ethanol Marketing Agreement

GFE currently has an Ethanol Marketing Agreement (“Eco Agreement”) with Eco-Energy, Inc. (“Eco-Energy”). Pursuant to the Eco Agreement, Eco-Energy agrees to purchase the entire ethanol output of GFE's ethanol plant and to arrange for the transportation of ethanol; however, GFE is responsible for securing all of the rail cars necessary for the transport of ethanol by rail. GFE will pay Eco-Energy a certain percentage of the FOB plant price in consideration of Eco-Energy's services. The contract had an initial term of one year, and will continue to remain in effect until terminated by either party at its unqualified option, by providing written notice of not less than 90 days to the other party.

Ethanol marketing fees and commissions totaled approximately $796,000, $743,000, and $1,006,000 for the fiscal years ended October 31, 2013, 2012 and 2011 respectively, and are included net within revenues.

During the fourth quarter of fiscal year 2013, HLBE entered into a new marketing agreement with Eco-Energy, for the sale of ethanol. Under this ethanol agreement, Eco-Energy will purchase, market and resell 100% of the ethanol produced at the Company's

52

GRANITE FALLS ENERGY, LLC AND SUBSIDIARIES

Notes to Consolidated Financial Statements

October 31, 2013 and 2012

ethanol production facility and the Company will pay Eco-Energy a marketing fee based on a percentage of the applicable sale price of the ethanol. The marketing fee was negotiated based on prevailing market-rate conditions for comparable ethanol marketing services.

Ethanol Contracts

At October 31, 2013, GFE had forward contracts to sell approximately $6,283,000 of ethanol for various delivery periods from November 2013 through December 2013 which approximates 36% of its anticipated ethanol sales during that period.

At October 31, 2012, GFE had forward contracts to sell approximately $8,747,000 of ethanol for delivery in November 2012.

Distillers Grain Marketing Agreement

GFE has a Marketing Agreement with RPMG, an unrelated party, for the purpose of marketing and selling all distillers grains produced by the Company. The contract commenced on February 1, 2011 with an initial term of one year, and will continue to remain in effect until terminated by either party at its unqualified option, by providing written notice of not less than 90 days to the other party. Distillers grain commissions totaled approximately $745,000, $650,000 and $460,000 for the fiscal years ended October 31, 2013, 2012 and 2011 respectively, and are included net within revenues.

At October 31, 2013, GFE had forward contracts to sell approximately $3,052,000 of distillers grains for delivery in November 2013 through March 2014 which approximates 27% of its anticipated distillers grain sales during that period.

At October 31, 2012, GFE had forward contracts to sell approximately $1,773,000 of distillers grains for delivery in November 2012 which approximates 65%.

Gavilon Ingredients, LLC serves as the distillers' grains marketer for HLBE pursuant to an off-take agreement that became effective as of November 1, 2013. Under this agreement, Gavilon Ingredients, LLC purchases all of the distillers' grains produced at our Heron Lake ethanol plant in exchange for a service fee.

Corn Oil Marketing Agreement

GFE has a Marketing Agreement with RPMG, an unrelated party, for the purpose of marketing and selling all corn oil produced by the Company. The contract commenced on April 29, 2010 with an initial term of one year, and will continue to remain in effect until terminated by either party at its unqualified option, by providing written notice of not less than 90 days to the other party. Corn oil commissions totaled approximately $74,000, $55,000 and $44,000 for the fiscal years ended October 31, 2013, 2012 and 2011 respectively, and are included net within revenues.

Natural Gas Contracts

At October 31, 2013, GFE had no forward contracts to purchase natural gas.

At October 31, 2012, GFE had forward contracts to purchase $719,000 of natural gas at prices with delivery periods from November 2012 through March 2013.    

HLBE has natural gas agreements with a minimum purchase commitment of approximately 1,600,000 MMBTU per year until October 31, 2014.

Contract for Natural Gas Pipeline to Plant

GFE has an agreement with an unrelated company for the construction of and maintenance of 9.5 miles of natural gas pipeline that will serve the plant. The agreement requires the Company to receive a minimum of 1,400,000 DT of natural gas annually through the term of the agreement. The Company is charged a fee based on the amount of natural gas delivered through the pipeline.

This agreement will continue in effect until December 31, 2015 at which time it will automatically renew for consecutive terms of one year. A twelve months prior written notice is required to be given by either party to terminate this agreement.

53

GRANITE FALLS ENERGY, LLC AND SUBSIDIARIES

Notes to Consolidated Financial Statements

October 31, 2013 and 2012

At the HLBE plant, we have a facilities agreement with Northern Border Pipeline Company which allows us access to an existing interstate natural gas pipeline located approximately 16 miles north from the plant. Agrinatural Gas, LLC ("Agrinatural Gas"), owned by our subsidiary, HLBE Pipeline Company, LLC, and Rural Energy Solutions, was formed to own and operate the pipeline and transports gas to HLBE pursuant to a transportation agreement. HLBE Pipeline Company, LLC owns 73% of Agrinatural Gas. HLBE also has a base agreement for the sale and purchase of natural gas with Constellation NewEnergy—Gas Division, LLC ("Constellation"). HLBE buys all of its natural gas from Constellation and this agreement runs for a three year period from November 1, 2011 to October 31, 2014.

13. CONCENTRATIONS

The Company has identified certain concentrations that are present in their business operations. GFE's revenue from ethanol sales is derived from a single customer under an ethanol marketing agreement described in Note 12. Sales under that agreement account for approximately 64%, 80% and 83% of the Company's consolidated revenues, net of derivative activity, during fiscal 2013, 2012 and 2011, respectively. Accordingly, 65% and 81% of the Company's consolidated receivable balance at October 31, 2013 and 2012, respectively, is related to that same customer. GFE's revenue from distillers grain and corn oil sales is derived from a single customer under a marketing agreement described in Note 12. Sales under that agreement account for approximately 19%, 21% and 17% of the Company's consolidated revenues, net of derivative activity, during fiscal 2013, 2012 and 2011, respectively. Accordingly, 20% and 18% of the Company's consolidated receivable balance at October 31, 2013 and 2012, respectively, is related to that same customer.

14.  LEGAL PROCEEDINGS

From time to time in the ordinary course of business, the Company may be named as a defendant in legal proceedings related to various issues, including without limitation, workers' compensation claims, tort claims, or contractual disputes.  We are not currently a party to any material pending legal proceedings and we are not currently aware of any such proceedings contemplated by governmental authorities.

54

GRANITE FALLS ENERGY, LLC AND SUBSIDIARIES

Notes to Consolidated Financial Statements

October 31, 2013 and 2012

15. QUARTERLY FINANCIAL DATA (UNAUDITED)

Summary quarterly results are as follows:

	First Quarter		Second Quarter		Third Quarter		Fourth Quarter
Fiscal year ended October 31, 2013
Revenues	$	47,117,122	$	48,020,602	$	48,884,076	$	80,079,134
Gross profit	832,144		3,629,972		2,710,179		6,581,018
Operating income	269,449		3,047,007		2,197,158		5,521,116
Net income attributable to GFE	221,427		3,031,943		2,173,701		4,874,950
Basic and diluted earnings per unit attributable to GFE	7.23		99.06		71.02		159.31

	First Quarter		Second Quarter		Third Quarter			Fourth Quarter
Fiscal year ended October 31, 2012
Revenues	$	43,745,776	$	39,025,122	$	42,435,763		$	49,955,382
Gross profit (loss)	3,687,950		657,416		54,694			(1,946,091		)
Operating income (loss)	3,024,214		66,935		(597,187		)	(2,489,589		)
Net income (loss)	3,042,288		116,466		(565,637		)	(2,432,510		)
Basic and diluted earnings (loss) per unit	99.29		3.81		(18.49		)	(79.36		)

	First Quarter		Second Quarter		Third Quarter		Fourth Quarter
Fiscal year ended October 31, 2011
Revenues	$	30,716,346	$	34,537,750	$	45,414,923	$	45,852,470
Gross profit	3,533,733		3,704,535		2,068,381		4,861,424
Operating income	2,975,612		3,245,729		1,550,481		4,393,545
Net income	3,011,596		3,270,110		1,586,882		4,423,268
Basic and diluted earnings per unit	98.24		106.67		51.76		144.29

The above quarterly financial data is unaudited, but in the opinion of management, all adjustments necessary for a fair presentation of the selected data for these periods presented have been included.

55

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

None.

ITEM 9A.    CONTROLS AND PROCEDURES

Disclosure Controls and Procedures

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

Our management, including our Chief Executive Officer and General Manager (the principal executive officer), Steve Christensen, along with our Chief Financial Officer (the principal financial officer), Stacie Schuler, have reviewed and evaluated the effectiveness of our disclosure controls and procedures as of October 31, 2013. Based upon this review and evaluation, these officers have concluded that our disclosure controls and procedures are effective to ensure that information required to be disclosed in the reports that we file or submit under the Exchange Act is recorded, processed, summarized and reported within the time periods 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

The Company’s 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. The Company’s 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 the Company’s 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 the Company’s receipts and expenditures are being made only in accordance with authorizations of the Company’s management and governors; and

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

Management, including the Company’s Chief Executive Officer and Chief Financial Officer, does not expect that the Company’s 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 evaluations of the effectiveness of controls in future periods are 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 Exchange Act, as amended) to provide reasonable assurance regarding the reliability of our financial reporting and the preparation of our financial statements for external purposes in accordance with U.S. generally accepted accounting principles.

56

Management conducted an evaluation of the effectiveness of the Company’s internal control over financial reporting based on the criteria set forth in Internal Control-Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission. Based on this evaluation, management has concluded that the Company’s internal control over financial reporting was effective as of October 31, 2013.

An attestation report from our accounting firm on our internal control over financial reporting is not included in this annual report because an attestation report is only required under the regulations of the Securities and Exchange Commission for accelerated filers and large accelerated filers.

Changes in Internal Control Over Financial Reporting.

There were no changes in our internal control over financial reporting during the fourth quarter of our 2013 fiscal year, which were identified in connection with management’s evaluation required by paragraph (d) of rules 13a-15 or 15d-15 under the Exchange Act, that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

ITEM 9B.    OTHER INFORMATION

Entry into a Material Definitive Agreement

On August 27, 2013, HLBE finalized Amendment No. 1 to Sixth Amended and Restated Master Loan Agreement (the “Amendment”) with AgStar Financial Services, PCA (“AgStar”). The Amendment amends certain provisions of the Sixth Amended and Restated Master Loan Agreement dated May 17, 2013 (the “MLA”) by and between HLBE and AgStar. The Amendment was effective as of July 31, 2013, which is the same date on which GFE indirectly, through Project Viking, L.L.C. (“Project Viking”), acquired a majority of HLBE's outstanding membership units and the same date on which GFE and HLBE entered into a Management Services Agreement, under which GFE supplies its personnel to act as part-time officers and managers of HLBE for the positions of Chief Executive Officer, Chief Financial Officer and Commodity Risk Manager. The following material amendments to the MLA are set forth in the Amendment: (i) the power of Project Viking or its affiliates to appoint a majority of HLBE’s governors is not defined as a “change of control” of HLBE; (ii) revolving advances under HLBE’s term revolving loan may be used for the purchase of corn inventory; (iii) The remaining amounts raised by HLBE in its offering (the “Offering”) of a maximum of $12 million in aggregate principal amount of promissory notes titled “7.25% Secured Subordinated Notes due 2018” (the "Notes") were to be paid to AgStar on or before October 1, 2013, whether subscribers in the Offering confirmed their subscriptions for notes or instead elected to convert the principal amount of their subscription into a subscription for HLBE’s membership units; and (iv) in light of the Management Services Agreement by and between GFE and HLBE, the prior requirements to identify and hire an interim and permanent Chief Executive Officer reasonably acceptable to AgStar by specified dates were removed. The Amendment is attached to this Annual Report as Exhibit 10.36.

On September 5, 2013, HLBE finalized a Corn Oil Marketing Agreement with RPMG, Inc. (“RPMG”) dated September 4, 2013. Pursuant to this agreement, HLBE will sell to RPMG, and RPMG will purchase and market, all of the corn oil produced by HLBE at HLBE's Heron Lake, Minnesota ethanol production plant. HLBE will pay RPMG a commission based on each pound of corn oil sold by RPMG. The agreement became effective as of September 16, 2013 and is attached to this Annual Report as Exhibit 10.37.

On September 19, 2013, HLBE finalized an Ethanol Marketing Agreement dated September 17, 2013 with Eco-Energy, LLC (“Eco-Energy”). Under the agreement, Eco-Energy will purchase the entire ethanol output of HLBE's Heron Lake, Minnesota ethanol production plant. Eco-Energy is required to use commercially reasonable efforts to solicit competitive market offers for the ethanol purchased from HLBE and to use reasonable efforts to optimize freight, fuel characteristics, and other marketing tools to provide competitive market pricing for HLBE's ethanol production. HLBE will pay Eco-Energy a marketing fee for its services under the agreement, as well as a lease fee for railcars leased from Eco-Energy to HLBE. The term of the agreement commenced on November 1, 2013. The agreement is attached to this Annual Report as Exhibit 10.38.

On September 24, 2013, HLBE finalized a Distiller's Grain Off-Take Agreement with Gavilon Ingredients, LLC (“Gavilon”). Under the agreement, Gavilon will purchase all of the distillers grains produced at HLBE's ethanol production facility in Heron Lake, Minnesota. Gavilon is required to use commercially reasonable efforts to achieve the highest price available under prevailing market conditions based on bids from Gavilon's customers and taking into account freight and other logistics costs. HLBE will pay Gavilon a service fee for its services under the agreement. The term of the agreement commenced on November 1, 2013. The agreement is attached to this Annual Report as Exhibit 10.39.

57

Entry into a Material Definitive AgreementandCreation of a Direct Financial Obligation or an Obligation under an Off-Balance Sheet Arrangement of a Registrant

On September 18, 2013, HLBE entered into an indenture (the “Indenture”) between HLBE and U.S. Bank National Association (“U.S. Bank”), as trustee and collateral agent, in connection with the closing of HLBE's Offering of the Notes. An aggregate principal amount of $4,143,000 of the Notes are governed by the Indenture. The Notes are subordinated secured obligations of HLBE, with interest payable on April 1 and October 1 of each year, beginning April 1, 2014, through the maturity date of October 1, 2018 at a rate of 7.25% per annum. The Notes are secured by a second mortgage and lien position on, among other assets, HLBE’s property, plant and equipment located in Heron Lake, Minnesota, which mortgage and lien position are junior to and subordinated to HLBE’s senior debt. Beginning on October 1, 2014, and each anniversary date thereafter prior to the maturity date of the Notes, and on the maturity date of the Notes, and prior to the effective time of any sale of all or substantially all of the assets of HLBE or merger or consolidation of HLBE with another person, subject to and upon compliance with the provisions of Article 4 of the Indenture, each holder of Notes has the right, at such holder’s option, to irrevocably convert all (but not less than all) of such holder’s Notes into the HLBE’s membership units at the rate of $0.30 of principal amount per unit. In addition to the anniversary and event conversion rights, prior to any prepayment date, each holder of Notes has the right, at such holder’s option, to irrevocably convert the principal amount to be prepaid into HLBE’s membership units at the rate of $0.30 of principal amount per unit. Subject to this conversion right, HLBE may, with at least 45 days but not more than 60 days notice to the holders thereof, prepay the outstanding amount of the Notes in whole or in part with accrued interest to the date of such prepayment on the amount prepaid, without penalty or premium, provided that any prepayment of Notes must be done pro rata to all holders of Notes. The Indenture provides for customary events of default.

PART III

Pursuant to General Instruction G(3), we omit Part III, Items 10, 11, 12, 13 and 14 and incorporate such items by reference to an amendment to this Annual Report on Form 10-K or to a 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 (October 31, 2013).

ITEM 10.    DIRECTORS, EXECUTIVE OFFICERS AND CORPORATE GOVERNANCE

The Information required by this Item is incorporated by reference to the 2014 Proxy Statement.

ITEM 11.     EXECUTIVE COMPENSATION

The Information required by this Item is incorporated by reference to the 2014 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 2014 Proxy Statement.

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

The Information required by this Item is incorporated by reference to the 2014 Proxy Statement.

ITEM 14. PRINCIPAL ACCOUNTANT FEES AND SERVICES.

The Information required by this Item is incorporated by reference to the 2014 Proxy Statement.

58

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 34 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

See the "Exhibit Index" following the signature pages.

59

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.

		GRANITE FALLS ENERGY, LLC
Date:	January 29, 2014	/s/ Steve Christensen
		Steve Christensen
		Chief Executive Officer
Date:	January 29, 2014	/s/ Stacie Schuler
		Stacie Schuler
		Chief Financial Officer

60

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.

Date:	January 29, 2014	/s/ Steve Christensen
		Steve Christensen, Chief Executive Officer and General Manager
		(Principal Executive Officer)
Date:	January 29, 2014	/s/ Stacie Schuler
		Stacie Schuler, Chief Financial Officer
		(Principal Financial and Accounting Officer)
Date:	January 29, 2014	/s/ Paul Enstad
		Paul Enstad, Governor and Chairman
Date:	January 29, 2014	/s/ Rodney R. Wilkison
		Rodney R. Wilkison, Governor and Vice Chairman
Date:	January 29, 2014	/s/ Dean Buesing
		Dean Buesing, Governor and Secretary
Date:	January 29, 2014	/s/ Leslie Bergquist
		Leslie Bergquist, Governor
Date:	January 29, 2014	/s/ Marten Goulet
		Marten Goulet, Governor
Date:	January 29, 2014	/s/ Kenton Johnson
		Kenton Johnson, Governor
Date:	January 29, 2014	/s/ Shannon Johnson
		Shannon Johnson, Governor
Date:	January 29, 2014	/s/ Myron Peterson
		Myron Peterson, Governor
Date:	January 29, 2014	/s/ David Thompson
		David Thompson, Governor
Date:	January 29, 2014	/s/ Marty Seifert
		Marty Seifert, Alternate Governor

61

GRANITE FALLS ENERGY, LLC

INDEX TO EXHIBITS TO FORM 10-K FOR FISCAL YEAR ENDED OCTOBER 31, 2013

Exhibit No.	Exhibit	Filed Herewith	Incorporated by Reference To:
3.1	Articles of Organization		Exhibit 3.1 to the registrant's Form SB-2 filed with the Commission on August 30, 2002 (File No. 000-51277).
3.2	Amendment of Articles of Organization		Exhibit 3.1 to the registrant's Form 10-QSB filed with the Commission on August 15, 2005 (File No. 000-51277).
3.3	Fifth Amended and Restated Operating and Member Control Agreement, First Amendment to the Fifth Amended and Restated Operating and Member Control Agreement and Second Amendment to the Fifth Amended and Restated Member Control Agreement		Exhibit 3.2 to the registrant's Form 10-QSB filed with the Commission on September 14, 2006 (File No. 000-51277).
3.4	Third Amendment to the Fifth Amended and Restated Operating and Member Control Agreement		Exhibit 3.1 to the registrant's Form 10-Q filed with the Commission on June 14, 2013 (File No. 000-51277).
4.1	Form of Membership Unit Certificate.		Exhibit 4.1 to the registrant's Pre-Effective Amendment No. 1 to Form SB-2 filed with the Commission on December 20, 2002 (File No. 000-51277).
10.1	Corn Storage and Delivery Agreement and Pre-Closing Memorandum dated October 6, 2003 between the Company and Farmers Cooperative Elevator Company.		Exhibit 10.2 to the registrant's Form 10-QSB filed with the Commission on November 14, 2003 (File No. 000-51277).
10.2	Grain Procurement Agreement with Farmers Cooperative Elevator Company.		Exhibit 10.2 to the registrant's Form 10-QSB filed with the Commission on November 15, 2004 (File No. 000-51277).
10.3	Electric Service Agreement dated August, 2004 with Minnesota Valley Cooperative Light and Power.		Exhibit 10.13 to the registrant's Form 10-KSB filed with the Commission on March 31, 2005 (File No. 000-51277).
10.4	Trinity Rail Proposal for Rail Cars.		Exhibit 10.16 to the registrant's Form 10-KSB filed with the Commission on March 31, 2005 (File No. 000-51277).
10.5	Job Opportunity Building Zone Business Subsidy Agreement.		Exhibit 10.17 to the registrant's Form 10-KSB filed with the Commission on March 31, 2005 (File No. 000-51277).
10.6	Ethanol Marketing Agreement with Eco-Energy, Inc. dated December 24, 2008. (+)		Exhibit 10.1 to the registrant's Form 10-K filed with the Commission on January 27, 2009 (File No. 000-51277).
10.7	Corn Oil Marketing Agreement between the registrant and Renewable Products Marketing Group, LLC dated April 29, 2010. (+)		Exhibit 10.1 to the registrant's Form 10-Q filed with the Commission on June 14, 2010 (File No. 000-51277).
10.8	Distillers Grains Marketing Agreement between RPMG, Inc. and Granite Falls Energy, LLC dated December 10, 2010. (+)		Exhibit 10.31 to the registrant's Form 10-K filed with the Commission on January 26, 2011 (File No. 000-51277).
10.9	Amended Employment Contract between Granite Falls Energy, LLC and Tracey Olson dated November 22, 2010.		Exhibit 10.30 to the registrant's Form 10-K filed with the Commission on January 26, 2011 (File No. 000-51277).
10.10	Insider Trading Policy of Granite Falls Energy, LLC dated February 17, 2011.		Exhibit 10.1 to the registrant's Form 10-Q filed with the Commission on March 16, 2011 (File No. 000-51277).
10.11	Ethanol Marketing Agreement Amendment No. 2 between Eco-Energy, Inc. and Granite Falls Energy, LLC dated August 30, 2011. (+)		Exhibit 99.1 to the registrant's Form 8-K filed with the Commission on September 1, 2011 (File No. 000-51277).

62

10.12	Amended Employment Contract between Tracey L. Olson and Granite Falls Energy, LLC dated November 21, 2011.	Exhibit 10.34 to the registrant's Form 10-K filed with the Commission on January 30, 2012 (File No. 000-51277).
10.13	CEO/GM Employment Contract between Steve Christensen and Granite Falls Energy, LLC dated April 19, 2012.	Exhibit 10.1 to the registrant's Form 10-Q filed with the Commission on June 14, 2012 (File No. 000-51277).
10.14	Master Loan Agreement between United FCS, PCA and Granite Falls Energy, LLC dated August 22, 2012.	Exhibit 10.14 to the registrant's Form 10-K filed with the Commission on January 29, 2013 (File No. 000-51277).
10.15	Revolving Term Loan Supplement between United FCS, PCA and Granite Falls Energy, LLC dated August 22, 2012.	Exhibit 10.15 to the registrant's Form 10-K filed with the Commission on January 29, 2013 (File No. 000-51277).
10.16	Monitored Revolving Credit Supplement between United FCS, PCA and Granite Falls Energy, LLC dated August 22, 2012.	Exhibit 10.16 to the registrant's Form 10-K filed with the Commission on January 29, 2013 (File No. 000-51277).
10.17	Membership Interest Purchase Agreement effective July 31, 2013 by and between Granite Falls Energy, LLC and Roland J. Fagen and Diane K. Fagen.	Exhibit 10.1 to the registrant's Form 10-Q filed with the Commission on September 16, 2013 (File No. 000-51277).
10.18	Subscription Agreement Including Investment Representations, dated July 31, 2013, by and between Heron Lake BioEnergy, LLC and Project Viking, L.L.C.	Exhibit 10.2 to the registrant's Form 10-Q filed with the Commission on September 16, 2013 (File No. 000-51277).
10.19	Subscription Supplement Agreement dated July 31, 2013, by and among Heron Lake BioEnergy, LLC, Granite Falls Energy, LLC and Project Viking, L.L.C.	Exhibit 10.3 to the registrant's Form 10-Q filed with the Commission on September 16, 2013 (File No. 000-51277).
10.20	Management Services Agreement effective as of July 31, 2013 between Granite Falls Energy, LLC and Heron Lake BioEnergy, LLC.	Exhibit 10.4 to the registrant's Form 10-Q filed with the Commission on September 16, 2013 (File No. 000-51277).
10.21	Secured Promissory Note dated July 31, 2013, between Roland (Ron) J. Fagen and Diane K. Fagen, jointly as Holder, and Granite Falls Energy, LLC, as Borrower.	Exhibit 10.5 to the registrant's Form 10-Q filed with the Commission on September 16, 2013 (File No. 000-51277).
10.22	Promissory Note, dated July 23, 2013, between Granite Falls Bank, as Lender, and Project Viking, L.L.C. and Roland J. (Ron) Fagen, as Borrower.	Exhibit 10.6 to the registrant's Form 10-Q filed with the Commission on September 16, 2013 (File No. 000-51277).
10.23	Assumption Agreement among Granite Falls Energy, LLC, Project Viking, L.L.C., Roland J. Fagen and Granite Falls Bank.	Exhibit 10.7 to the registrant's Form 10-Q filed with the Commission on September 16, 2013 (File No. 000-51277).
10.24	Creditor and Debtors Agreement dated July 31, 2013 by and among Granite Falls Energy, LLC, Project Viking, L.L.C., Roland “Ron” J. Fagen and Granite Falls Bank.	Exhibit 10.8 to the registrant's Form 10-Q filed with the Commission on September 16, 2013 (File No. 000-51277).
10.25	Revolving Credit Supplement dated July 26, 2013 between United FCS, PCA and Granite Falls Energy, LLC.	Exhibit 10.9 to the registrant's Form 10-Q filed with the Commission on September 16, 2013 (File No. 000-51277).
10.26	Member Control Agreement of Heron Lake BioEnergy, LLC, as amended through August 30, 2011.	Exhibit 3.2 to Heron Lake BioEnergy, LLC's ("HLBE's") Form 8-K dated September 2, 2011 (File No. 000-51825).
10.27	Indenture dated as of September 18, 2013, by and between Heron Lake BioEnergy, LLC and U.S. Bank National Association.	Exhibit 4.1 to HLBE's Form 8-K dated September 8, 2013 (File No. 000-51825).
10.28	Industrial Water Supply Development and Distribution Agreement dated October 27, 2003 among Heron Lake BioEnergy, LLC (f/k/a Generation II Ethanol, LLC), City of Heron Lake, Jackson County, and Minnesota Soybean Processors.	Exhibit 10.10 to HLBE's Registration Statement on Form 10 filed on August 22, 2008 (the "2008 Registration Statement") (File No. 000-51825).

63

10.29	Industrial Water Supply Treatment Agreement dated May 23, 2006 among Heron Lake BioEnergy, LLC, City of Heron Lake and County of Jackson.		Exhibit 10.11 to HLBE's 2008 Registration Statement (File No. 000-51825).
10.30	Secured Promissory Note issued December 28, 2007 by Heron Lake BioEnergy, LLC as borrower to Federated Rural Electric Association as lender in principal amount of $600,000.		Exhibit 10.20 to HLBE's 2008 Registration Statement (File No. 000-51825).
10.31	Electric Service Agreement dated October 17, 2007 by and between Interstate Power and Light Company and Heron Lake BioEnergy, LLC.		Exhibit 10.22 to HLBE's 2008 Registration Statement (File No. 000-51825).
10.32	Sixth Amended and Restated Master Loan Agreement dated to be effective as of May 17, 2013 by and among AgStar Financial Services, PCA and Heron Lake BioEnergy, LLC.		Exhibit 10.1 to HLBE's Form 10-Q for the quarter ended April 30, 2013 (File No. 000-51825).
10.33	Second Amended and Restated Term Note dated May 17, 2013 in principal amount of $17,404,344 by Heron Lake BioEnergy, LLC to AgStar Financial Services, PCA as lender.		Exhibit 10.2 to HLBE's Form 10-Q for the quarter ended April 30, 2013 (File No. 000-51825).
10.34	Second Amended and Restated Term Revolving Note dated May 17, 2013 in principal amount of $20,500,000 by Heron Lake BioEnergy, LLC to AgStar Financial Services, PCA as lender.		Exhibit 10.3 to HLBE's Form 10-Q for the quarter ended April 30, 2013 (File No. 000-51825).
10.35	Sixth Amended and Restated Mortgage, Security Agreement and Assignment of Rents and Leases dated May 17, 2013 between Heron Lake BioEnergy, LLC and AgStar Financial Services, PCA.		Exhibit 10.4 to HLBE's Form 10-Q for the quarter ended April 30, 2013 (File No. 000-51825).
10.36	Amendment No. 1 to Sixth Amended and Restated Master Loan Agreement dated effective as of July 31, 2013 between Heron Lake BioEnergy, LLC and AgStar Financial Services, PCA.		Exhibit 10.1 to HLBE's Form 8-K dated August 27, 2013 (File No. 000-51825).
10.37	Corn Oil Marketing Agreement dated September 4, 2013 by and among Heron Lake BioEnergy, LLC and RPMG, Inc. (+)		Exhibit 10.76 to HLBE's Form 10-K for the year ended October 31, 2013 (File No. 000-51825).
10.38	Ethanol Marketing Agreement dated September 17, 2013 by and among Heron Lake BioEnergy, LLC and Eco-Energy, LLC. (+)		Exhibit 10.77 to HLBE's Form 10-K for the year ended October 31, 2013 (File No. 000-51825).
10.39	Distiller's Grain Off-Take Agreement dated September 24, 2013 by and among Heron Lake Bio-Energy, LLC and Gavilon Ingredients, LLC. (+)		Exhibit 10.78 to HLBE's Form 10-K for the year ended October 31, 2013 (File No. 000-51825).
10.40	Amendment No. 3 Ethanol Marketing Agreement dated September 17, 2013 by and between Eco-Energy, LLC and Granite Falls Energy, LLC. (+)	X
14.1	Code of Ethics		Exhibit 14.1 to the registrant's Form 10-KSB filed with the Commission on March 30, 2004 (File No. 000-51277).
21.1	Subsidiaries of the registrant	X
31.1	Certification of Chief Executive Officer pursuant to 17 CFR 240.13a-14(a)	X
31.2	Certification of Chief Financial Officer pursuant to 17 CFR 240.13a-14(a)	X
32.1	Certification of Chief Executive Officer pursuant to 18 U.S.C. Section 1350	X

64

32.2	Certification of Chief Financial Officer pursuant to 18 U.S.C. Section 1350	X
101	The following financial information from Granite Falls Ethanol, LLC's Annual Report on Form 10-K for the fiscal year ended October 31, 2013, formatted in XBRL (eXtensible Business Reporting Language): (i) Balance Sheets as of October 31, 2013 and October 31, 2012, (ii) Statements of Operations for the fiscal years ended October 31, 2013, 2012, and 2011, (iii) Statement of Changes in Members' Equity; (iv) Statements of Cash Flows for the fiscal years ended October 31, 2013, 2012, and 2011, and (v) the Notes to Financial Statements.**

(+) Confidential Treatment Requested.

(**) Furnished herewith.

65

EX-10.40

CERTAIN INFORMATION INDICATED BY [***] HAS BEEN DELETED FROM THIS EXHIBIT AND FILED SEPARATELY WITH THE SECURITIES AND EXCHANGE COMMISSION PURSUANT TO A REQUEST FOR CONFIDENTIAL TREATMENT UNDER RULE 24b-2.

AMENDMENT NO. 3

ETHANOL MARKETING AGREEMENT

THIS Amendment No. 3 (“Amendment 3”), dated September 17, 2013, is entered into by and between Eco-Energy, LLC, a Tennessee Limited Liability Corporation with its registered office at 725 Cool Springs Boulevard, Suite 500, Franklin, Tennessee 37067 (“Eco”), and Granite Falls Energy, LLC (“GFE”), a Minnesota Limited Liability Corporation with its main office at 15045 Highway 23 SE, Granite Falls, Minnesota 56241. Eco and GFE are hereinafter also referred to collectively as the “Parties.”

RECITALS

A.    The Parties previously entered an Ethanol Marketing Agreement (“Agreement”), executed December 24, 2008, where the Parties established certain terms and conditions relating to Eco’s rights and obligations regarding the purchase of GFE’s entire ethanol output. The Agreement established a term which commenced on the first day of ethanol shipment and expired one (1) year thereafter. A copy of the Agreement—including Exhibit A, Exhibit B and Exhibit C of the Agreement—is attached hereto as Appendix 1.

B.    On October 22, 2009, the Parties entered into Amendment No. 1 to the Agreement (attached hereto as Appendix 2), which modified the Agreement as follows: (i) added a “flex fee” adjustment intended to minimize the costs effects of disadvantageous production price fluctuations for GFE and (ii) extended the expiration date of the Agreement until December 31, 2011.

C.    On August 30, 2011, the Parties entered into Amendment No. 2 to the Agreement (attached hereto as Appendix 3), which modified the Agreement as follows: (i) terminated the “flex fee” adjustment specified in Amendment No. 1 to the Agreement, ii) extended the expiration date of the Agreement until December 31, 2013, and iii) adjusted the Payment and Fees section of the Agreement by changing the fee that GFE pays Eco for Marketing Fees from [***] to [***].

D.    The Parties now desire to again alter the Agreement in order to memorialize the modifications recently agreed upon by the Parties as well as incorporate such modifications into the Agreement.

NOW, THEREFORE, the written signatures of the Parties integrate this Amendment No. 3 into the Agreement making it a binding, and legally enforceable, portion of such. For good and valuable consideration, the receipt and sufficiency of which is hereby acknowledged, Eco and GFE agree as follows:

I. EFFECTIVE DATE: The modifications specified in Paragraph II of this Amendment No. 3 shall become effective on November 1, 2013.

II. MODIFICATIONS:

1)    Add the following language to the end of Section 2 of the Agreement:

“If GFE obtains a more favorable third party product price quote than that which Eco is able to offer, and the quote is comparable in regard to term and structure, GFE shall provide notice to Eco of the offer specifying the counterparty, quantity, and specification. Upon receiving the aforementioned notification, Eco shall have the right, but not the obligation, to match the offer or transact directly with the third party if they meet Eco credit requirements.”

#2419605

2)    Section 4 of the Agreement—as amended by Amendment No. 1 and Amendment No. 2—is hereby deleted in its entirety and replaced with the following:

4.    Payment and Fees.

(a) [***].

(b) Eco shall make payment to GFE within [***]. If GFE desires to receive payment more expeditiously than the aforementioned [***], Eco will act in good faith to accommodate the request; however, the expedited payment to GFE will be charged an additional daily interest expense equal to the Wall Street Journal Prime Rate plus 2.75% based on the number of days each payment is expedited.

(c) [***].

3)    Section 11(a) and Section 11(b) of the Agreement, as previously modified by Amendment No. 1 and Amendment No. 2, is hereby amended as follows:

11.    Terms and Termination.

(a) The term of this Agreement shall expire on December 31, 2016.

(b) This Agreement will automatically renew for additional consecutive terms of three (3) years each unless either party hereto gives written notice to the other at least three (3) months prior to the end of the term or the then current renewal term, in which case this Agreement shall terminate at the end of the term or such then current renewal term.

4)    Add a paragraph (h) to Section 20 as follows:

20.    General.

(h)    Eco is obligated to provide GFE with undenatured export offers on a continuous basis during the Term in an effort to assist GFE in managing its Renewable Identification Number (RIN) regulatory requirements.

5)    Exhibit B of the Agreement is hereby deleted in its entirety and replaced with the following:

Exhibit B

Eco Transportation Services

1. Eco will provide GFE forty-three (43) railcars for the transportation of ethanol. The lease(s) of these forty-three (43) railcars will be in the name of Eco; however, GFE will be responsible for ensuring compliance with the applicable manufactures Railcar Service Agreement(s). The monthly sublease fee owed by GFE for the aforementioned railcars will be $750.00 per railcar until the expiration of the Term (i.e., December 31, 2016).

2. Eco will purchase all truck and railcar gallons on a FOB plant basis.

2

3. Eco will negotiate all rail and truck rates on behalf of GFE.

4. Eco will be responsible for remitting payment for all rail and truck carrier expenses.

6)    Exhibit A, Section 1, is hereby deleted and replaced with the following:

1)    Eco shall make a payment to GFE within [***]. If GFE desires to receive payment more expeditiously than the aforementioned [***], Eco will act in good faith to accommodate the request; however, expedited payment amount to GFE will be charged an additional daily interest expense equal to the Wall Street Journal Prime Rate plus 2.75% based on the number of days each payment is expedited.

III. EFFECT OF AMENDMENT No. 3: Except as expressly modified in Section II of this Amendment No. 3 the Agreement—including Amendment No. 1 and Amendment No. 2—remains unchanged and in full force and effect.

IV. ENTIRETIES: This Amendment No. 3 represents the final agreement between the parties regarding the subject matter hereof and may not be contradicted by evidence or prior, contemporaneous, or subsequent oral agreements of the parties. There are no unwritten oral agreements between the parties.

ECO ENERGY, LLC.    GRANITE FALLS ENERGY, LLC.

By: /s/ Chad Martin        By: /s/ Steve A. Christensen    

Name: Chad Martin        Name: Steve A. Christensen    

Title: CEO        Title: CEO & GM    

Date: 9/19/13        Date: 09/17/2013    

3

EX-21.1

Subsidiaries of Granite Falls Energy, LLC

Name	State of Organization
Project Viking, L.L.C.	Minnesota
Heron Lake BioEnergy, LLC	Minnesota

EX-31.1

CERTIFICATION PURSUANT TO 17 CFR 240.15d-14(a)

(SECTION 302 CERTIFICATION)

I, Steve Christensen, certify that:

1. I have reviewed this annual report on Form 10-K of Granite Falls Energy, 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 officers 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 officers 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:	January 29, 2014	/s/ Steve Christensen
		Steve Christensen, Chief Executive Officer (Principal Executive Officer)

EX-31.2

CERTIFICATION PURSUANT TO 17 CFR 240.15d-14(a)

(SECTION 302 CERTIFICATION)

I, Stacie Schuler, certify that:

1. I have reviewed this annual report on Form 10-K of Granite Falls Energy, 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 officers 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 officers 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:	January 29, 2014	/s/ Stacie Schuler
		Stacie Schuler, Chief Financial Officer (Principal 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 the annual report on Form 10-K of Granite Falls Energy, LLC (the “Company”) for the fiscal year ended October 31, 2013, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Steve Christensen, 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.

/s/ Steve Christensen

Steve Christensen, Chief Executive Officer

Dated: January 29, 2014

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 the annual report on Form 10-K of Granite Falls Energy, LLC (the “Company”) for the fiscal year ended October 31, 2013, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Stacie Schuler, 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.

/s/ Stacie Schuler

Stacie Schuler, Chief Financial Officer

Dated: January 29, 2014

XML

Inventory Inventory (Details) (USD $)	Oct. 31, 2013	Oct. 31, 2012
Inventory, Net	$ 12,370,277	$ 12,013,169
Raw Materials [Member]
Inventory, Net	4,652,465	8,977,820
Replacement Parts [Member]
Inventory, Net	1,636,466	584,011
Work In Process [Member]
Inventory, Net	1,643,574	1,150,239
Finished Goods [Member]
Inventory, Net	$ 4,437,772	$ 1,557,546

XML

Employee Benefit Plans Narrative (Details) (USD $)	12 Months Ended
	Oct. 31, 2013	Oct. 31, 2012	Oct. 31, 2011
Defined Benefit Plan Disclosure [Line Items]
Deferred Salary, Company Match	50.00%
Description of Defined Contribution Pension and Other Postretirement Plans	3.00%
Defined Benefit Plan, Net Periodic Benefit Cost	$ 50,000	$ 51,000	$ 46,000

XML

Fair Value Derivative Instrument (Details) (USD $)	Oct. 31, 2013	Oct. 31, 2012
Carrying (Reported) Amount, Fair Value Disclosure [Member]
Derivative [Line Items]
Derivative Liabilities	$ (75,113)	$ (45,563)
Fair Value, Inputs, Level 1 [Member]
Derivative [Line Items]
Derivative Liabilities	(75,113)	(45,563)
Fair Value, Inputs, Level 1 [Member]
Derivative [Line Items]
Derivative Liabilities	(75,113)	(45,563)
Fair Value, Inputs, Level 2 [Member]
Derivative [Line Items]
Derivative Liabilities	0	0
Fair Value, Inputs, Level 3 [Member]
Derivative [Line Items]
Derivative Liabilities	$ 0	$ 0

XML

Summary of Significant Accounting Policies P,P, & E Useful Life (Details)	12 Months Ended
	Oct. 31, 2013
Land Improvements [Member] | Minimum [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Useful Life	5 years
Land Improvements [Member] | Maximum [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Useful Life	20 years
Building and Building Improvements [Member] | Minimum [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Useful Life	10 years
Building and Building Improvements [Member] | Maximum [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Useful Life	30 years
Grain Handling Equipment [Member] | Minimum [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Useful Life	5 years
Grain Handling Equipment [Member] | Maximum [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Useful Life	15 years
Mechanical Equipment [Member] | Minimum [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Useful Life	5 years
Mechanical Equipment [Member] | Maximum [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Useful Life	15 years
Office Equipment [Member] | Minimum [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Useful Life	5 years
Office Equipment [Member] | Maximum [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Useful Life	10 years

XML

Acquisition (Tables)

12 Months Ended

Oct. 31, 2013

Fair Value of Cash Used [Abstract]

Fair Value, by Balance Sheet Grouping [Table Text Block]

The acquisition date fair value of the consideration transferred consisted of the following:

Cash	$	8,000,000
Note payable	4,024,500
Assumption of note payable to Granite Falls Bank	5,000,000
Total Consideration	$	17,024,500

The following table provides information on those derivative assets measured at fair value on a recurring basis at October 31, 2013:

	Carrying Amount in Balance Sheet October 31, 2013			Fair Value October 31, 2013			Fair Value Measurement Using
							Quoted Prices in Active Markets (Level 1)			Significant Other Observable Inputs (Level 2)		Significant unobservable inputs (Level 3)
Financial Liabilities:
Derivative Instruments	$	(75,113	)	$	(75,113	)	$	(75,113	)	$	—	$	—

The following table provides information on those derivative assets measured at fair value on a recurring basis at October 31, 2012:

	Carrying Amount in Balance Sheet October 31, 2012			Fair Value October 31, 2012			Fair Value Measurement Using
							Quoted Prices in Active Markets (Level 1)			Significant Other Observable Inputs (Level 2)		Significant unobservable inputs (Level 3)
Financial Liabilities:
Derivative Instruments	$	(45,563	)	$	(45,563	)	$	(45,563	)	$	—	$	—

Schedule of Business Acquisitions, by Acquisition [Table Text Block]

Cash	$	1,022,764
Restricted cash	510,955
Accounts receivable	3,107,121
Inventory	2,303,157
Prepaid expenses	1,107,025
Property, plant, and equipment	51,625,774
Other assets	924,252
Goodwill	1,372,473
Total assets acquired	$	61,973,521
Accounts payable	$	(936,893	)
Accrued expenses	(399,623		)
Notes payable	(36,452,764		)
Non-controlling interest	(7,159,741		)
Net purchase price	$	17,024,500

BUSINESS COMBINATION

On July 31, 2013, the Company acquired 63.3% of the outstanding membership units of Heron Lake BioEnergy, LLC (“HLBE”) through its purchase of 100% of the membership units of Project Viking, L.L.C. (“Project Viking”), for a total purchase price of $17,024,500. HLBE is a 50 million gallon per year ethanol plant located in Heron Lake, Minnesota. Project Viking was formed by the previous investor to only hold equity interests in HLBE and the debt incurred to obtain those interests and did not have any other assets or liabilities. The previous owner of Project Viking also owned approximately 12.82% of the outstanding membership units of the Company at July 31, 2013.

Immediately following the closing, the Company, through its 100% ownership of Project Viking, owned 24,080,949 Class A units and 15,000,000 Class B units of HLBE, for a total of 39,080,949 units, or 63.3% of the 61,697,104 outstanding units. As a result, under HLBE's member control agreement, Project Viking is entitled to appoint five (5) of the nine (9) governors to HLBE's board of governors.

On July 31, 2013, the Company entered into a Management Services Agreement with HLBE. Under the Management Services Agreement, the Company agreed to supply its own personnel to act as part-time officers and managers of HLBE for the positions of Chief Executive Officer, Chief Financial Officer, and Commodity Risk Manager. The initial term of the Management Services Agreement is three years. The Company will be paid $35,000 per month by HLBE for the first year of the Management Services Agreement. During years two and three of the agreement, HLBE agreed to pay the Company 50% of the total salary, bonuses, and other expenses and costs incurred by the Company for the three management positions. At the expiration of the initial term, the Management Services Agreement will automatically renew for successive one-year terms unless and until the Company or HLBE gives the other party 90-days written notice of termination prior to expiration of the initial term or the start of a renewal term.

The acquisition date fair value of the consideration transferred consisted of the following:

Cash	$	8,000,000
Note payable	4,024,500
Assumption of note payable to Granite Falls Bank	5,000,000
Total Consideration	$	17,024,500

The assets and liabilities of Project Viking were recorded at their respective estimated fair values as of the date of the acquisition using generally accepted accounting principles for business combinations. The Company used a combination of the market and cost approaches that included unobservable level 3 inputs, to estimate the fair values of the assets acquired and liabilities assumed. The fair value of the long-term debt acquired was determined based on the present value of future contractual cash flows discounted at an interest rate that reflects the current borrowing rates available to the Company for loans with similar terms. The fair market value of the debt assumed was approximately $36.5 million and resulted in a debt premium balance of approximately $2.3 million being recorded as of the acquisition date. The debt premium is amortized as a reduction of interest expense over the term of the debt using the effective interest method. The value of the 36.66% noncontrolling interest was determined by using the fair value method by using the most recent arms-length transaction of HLBE's units that did not include a control premium. The goodwill is attributable to the synergies expected to arise after the acquisition in the purchasing of inputs and the sale of outputs.  Goodwill is not expected to be deductible for tax purposes.  The fair value of the assets acquired includes account receivables of approximately $3,107,000, all of which are expected to be collectible.

Subsequent to the initial purchase price allocation and within the one year measurement period, new information was obtained about facts and circumstances that existed as of the acquisition date. As such, the purchase price allocation of the HLBE acquisition was retroactively adjusted to include the effect of this measurement period adjustment.  An adjustment of approximately $273k was recorded to adjust the fair value of a noncontrolling interest in HLBE, which was adjusted through goodwill during the fourth quarter ended October 31, 2013. The retroactively adjusted purchase price allocation is as follows:

Cash	$	1,022,764
Restricted cash	510,955
Accounts receivable	3,107,121
Inventory	2,303,157
Prepaid expenses	1,107,025
Property, plant, and equipment	51,625,774
Other assets	924,252
Goodwill	1,372,473
Total assets acquired	$	61,973,521
Accounts payable	$	(936,893	)
Accrued expenses	(399,623		)
Notes payable	(36,452,764		)
Non-controlling interest	(7,159,741		)
Net purchase price	$	17,024,500

The acquisition occurred on the last day of the Company's fiscal third quarter, therefore the Company consolidated three months of HLBE's revenues and expenses in the consolidated statements of operations. HLBE contributed revenues of $38,560,522 and earnings of $1,305,044 to the Company for the three month period from August 1, 2013 to October 31, 2013. The net income attributable to non-controlling interests for the year ended October 31, 2013 totaled approximately $527,000.

The following represents the unaudited pro forma consolidated statement of operations as if the transaction occurred at the beginning of the following periods:

	For the years ended
	October 31, 2013		October 31, 2012			October 31, 2011
	Unaudited		Unaudited			Unaudited
Revenues	$	349,304,556	$	343,821,978		$	320,641,864
Net income, including portion attributable to non-controlling interest of $712,289, ($20,702,684), and $361,351, respectively	$	4,864,820	$	(31,794,779	)	$	13,612,987
Earnings per share (30,606, 30,614, and 30,656 weighted average units outstanding - basic and diluted, respectively)	$	116.16	$	(617.00	)	$	412.75

The pro forma financial information is presented for informational purposes only and is not indicative of the results of operations that would have been achieved if the acquisition had taken place at the beginning of each of the periods presented. These amounts have been calculated after adjusting the results of HLBE to reflect the additional amortization of the debt premium that would have occurred assuming the fair value adjustment to long-term debt had been applied at the beginning of each period presented.

Business Acquisition, Pro Forma Information [Table Text Block]

The following represents the unaudited pro forma consolidated statement of operations as if the transaction occurred at the beginning of the following periods:

	For the years ended
	October 31, 2013		October 31, 2012			October 31, 2011
	Unaudited		Unaudited			Unaudited
Revenues	$	349,304,556	$	343,821,978		$	320,641,864
Net income, including portion attributable to non-controlling interest of $712,289, ($20,702,684), and $361,351, respectively	$	4,864,820	$	(31,794,779	)	$	13,612,987
Earnings per share (30,606, 30,614, and 30,656 weighted average units outstanding - basic and diluted, respectively)	$	116.16	$	(617.00	)	$	412.75

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Commitments and Contingencies Narrative (Details) (USD $)	3 Months Ended	12 Months Ended
	Jan. 31, 2013	Oct. 31, 2013	Oct. 31, 2012	Oct. 31, 2011
Purchase Commitment, Excluding Long-term Commitment [Line Items]
Selling and Marketing Expense		$ 796,000	$ 743,000	$ 1,006,000
Entity-Wide Revenue, Major Customer, Percentage	100.00%
Natural Gas [Member]
Purchase Commitment, Excluding Long-term Commitment [Line Items]
Future Commitment, Dollar		0	719,000
Future Commitments, Natural Gas		1,600,000
Future Commitment, Pipeline		9.5
Future Commitment, DT		1,400,000
Corn Contracts [Member]
Purchase Commitment, Excluding Long-term Commitment [Line Items]
Inventory Dollars, Outside Storage		2,346,000
Accounts Payable		4,002,000	1,996,000
Commitments and Contingencies		350,000
Inventory, Outside storage		550,000
Purchases For Inventory		153,216,000	148,289,000	123,676,000
Ethanol Contracts [Member]
Purchase Commitment, Excluding Long-term Commitment [Line Items]
Future Commitment, Dollar		6,283,000	8,747,000
Revenue Concentration, Future Commitment		36.00%
Distillers Grains [Member]
Purchase Commitment, Excluding Long-term Commitment [Line Items]
Future Commitment, Dollar		3,052,000	1,773,000
Revenue Concentration, Future Commitment		27.00%	65.00%
Initial Length [Member]
Purchase Commitment, Excluding Long-term Commitment [Line Items]
Written Notice		P1Y
Renewal Notice [Member]
Purchase Commitment, Excluding Long-term Commitment [Line Items]
Written Notice		P90D
Corn Oil [Member]
Purchase Commitment, Excluding Long-term Commitment [Line Items]
Written Notice		90 days
Contract, Initial Length		one year
Fees and Commissions		(74,000)	(55,000)	(44,000)
Distillers Grains [Member]
Purchase Commitment, Excluding Long-term Commitment [Line Items]
Written Notice		P90D
Contract, Initial Length		P1Y
Fees and Commissions		$ (745,000)	$ (650,000)	$ (460,000)
Natural Gas [Member]
Purchase Commitment, Excluding Long-term Commitment [Line Items]
Written Notice		P12M
Contract, Initial Length		P1Y

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Derivative Instrument, Income Statement (Details) (USD $)	12 Months Ended
	Oct. 31, 2013	Oct. 31, 2012	Oct. 31, 2011
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Instruments, Gain (Loss) Recognized in Income, Net	$ 155,563	$ (1,651,799)	$ 1,271,242
Corn Contracts [Member]
Derivative Instruments, Gain (Loss) [Line Items]
derivative cost of goods	155,563	(1,651,799)	1,280,413
Natural Gas [Member]
Derivative Instruments, Gain (Loss) [Line Items]
derivative cost of goods	0	0	(4,545)
Ethanol Contracts [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Instruments, Ethanol Revenue	$ 0	$ 0	$ (4,626)

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Acquisition (Details) (USD $)	9 Months Ended	12 Months Ended					3 Months Ended	12 Months Ended			3 Months Ended
	Jul. 31, 2013 governor	Oct. 31, 2013	Oct. 31, 2012	Oct. 31, 2011	Oct. 31, 2010	Jul. 31, 2013 Project Viking, LLC [Member]	Jul. 31, 2013 Heron Lake Bioenergy [Member] gal	Oct. 31, 2013 Heron Lake Bioenergy [Member]	Oct. 31, 2012 Heron Lake Bioenergy [Member]	Oct. 31, 2011 Heron Lake Bioenergy [Member]	Jul. 31, 2013 Capital Unit, Class A [Member]	Jul. 31, 2013 Capital Unit, Class B [Member]
Business Acquisition [Line Items]
Net Income (Loss) Attributable to Noncontrolling Interest		$ 526,752	$ 0	$ 0				$ 527,000
Debt Instrument, Fair Value Disclosure								36,500,000
Debt premium								2,300,000
Business Acquisition, Pro Forma Revenue		349,304,556	343,821,978	320,641,864
Cash Acquired from Acquisition		1,158,774	685,828	13,064,560	10,664,225		1,022,764
Business Acquisition, Cost of Acquired Entity, Cash Paid	8,000,000
Equity Method Investment, Ownership Percentage	12.82%					100.00%	63.30%
Business Acquisition, Cost of Acquired Entity, Purchase Price	17,024,500						17,024,500
Plant production capacity							50,000,000
Membership Units, Acquired							39,080,949				24,080,949	15,000,000
Membership Units, Issued		30,606	30,606	30,656			61,697,104
Board of Governors, Seats Appointed	5
Board of Governors, Total Seats	9
Noncontrolling Interest, Ownership Percentage by Noncontrolling Owners		39.20%					36.66%
Business Acquisition, Purchase Price Allocation, Notes Payable and Long-term Debt	4,024,500
Business Acquisition, Cost of Acquired Entity, Liabilities Incurred	5,000,000
Restricted Cash and Cash Equivalents		393,750	494,000				510,955
Accounts Receivable, Net, Current							3,107,121	3,107,000
Inventory, Net		12,370,277	12,013,169				2,303,157
Prepaid Expense, Current							1,107,025
Property, Plant and Equipment, Net		88,808,855	40,418,082				51,625,774
Other Assets, Noncurrent							924,252
Goodwill		1,372,473	0				1,372,473
Total Assets		112,673,222	61,133,132				61,973,521
Accounts Payable, Current		3,058,633	3,527,840				(936,893)
Accrued Liabilities, Current		696,858	318,819				(399,623)
Notes Payable							(36,452,764)
Stockholders' Equity Attributable to Noncontrolling Interest		8,480,657	0				(7,159,741)
Business Acquisition, Pro Forma Net Income (Loss)		4,864,820	(31,794,779)	13,612,987				712,289	(20,702,684)	361,351
Earnings Per Share, Basic and Diluted		$ 327.78	$ 5.25	$ 400.96				$ 116.16	$ (617.00)	$ 412.75
Management Services Agreement, Initial Term							three
Management Services Agreement, Monthly Fee, Year 1							35,000
Management Serices Agreement, Monthly Fee Percent of Salaries, Year 2							50.00%
Management Services Agreement, Termination Notice							90-days
Goodwill, Allocation Adjustment								273,000
Business Combination, Separately Recognized Transactions, Revenues and Gains Recognized								38,560,522
Business Combinations, Separately Recognized TRansactions, net earnings recognized								$ 1,305,044
Weighted Average Number of Shares Outstanding, Basic								30,606	30,656	30,614
Weighted Average Number of Shares Outstanding, Diluted								30,606	30,656	30,614

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Quarterly Financial Data (Unaudited) Quarterly Financial Data (Details) (USD $)	3 Months Ended												12 Months Ended
	Oct. 31, 2013	Jul. 31, 2013	Apr. 30, 2013	Jan. 31, 2013	Oct. 31, 2012	Jul. 31, 2012	Apr. 30, 2012	Jan. 31, 2012	Oct. 31, 2011	Jul. 31, 2011	Apr. 30, 2011	Jan. 31, 2011	Oct. 31, 2013	Oct. 31, 2012	Oct. 31, 2011
Quarterly Financial Information Disclosure [Abstract]
Revenues	$ 80,079,134	$ 48,884,076	$ 48,020,602	$ 47,117,122	$ 49,955,382	$ 42,435,763	$ 39,025,122	$ 43,745,776	$ 45,852,470	$ 45,414,923	$ 34,537,750	$ 30,716,346	$ 224,100,934	$ 175,162,043	$ 156,521,489
Gross Profit	6,581,018	2,710,179	3,629,972	832,144	(1,946,091)	54,694	657,416	3,687,950	4,861,424	2,068,381	3,704,535	3,533,733	14,023,313	2,453,969	14,168,073
Operating Income (Loss)	5,521,116	2,197,158	3,047,007	269,449	(2,489,589)	(597,187)	66,935	3,024,214	4,393,545	1,550,481	3,245,729	2,975,612	11,034,730	4,373	12,165,367
Net Income (Loss) Available to Members	$ 4,874,950	$ 2,173,701	$ 3,031,943	$ 221,427	$ (2,432,510)	$ (565,637)	$ 116,466	$ 3,042,288	$ 4,423,268	$ 1,586,882	$ 3,270,110	$ 3,011,596
Earnings Per Share, Diluted	$ 159.31	$ 71.02	$ 99.06	$ 7.23	$ (79.36)	$ (18.49)	$ 3.81	$ 99.29	$ 144.29	$ 51.76	$ 106.67	$ 98.24

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Members' Equity Narrative (Details) (USD $)	1 Months Ended			12 Months Ended
	Oct. 31, 2011	Nov. 30, 2010	Nov. 30, 2009	Oct. 31, 2013	Oct. 31, 2011	Oct. 31, 2012
Capital Unit [Line Items]
Membership Units, Issued	30,656			30,606	30,656	30,606
Membership Units, Outstanding	30,656			30,606	30,656	30,606
Membership Units, Redeemed					50
Membership Unit Value, Redeemed					$ 66,420
Distribution Made to Membership, Cash Distribution Paid per Unit	300	300	150	180
Distribution Made to Member or Limited Partner, Cash Distributions Paid	$ 9,196,800	$ (9,196,800)	$ (4,598,400)	$ 5,509,080	$ (18,393,600)

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Risks and Uncertainties

12 Months Ended

Oct. 31, 2013

Item 2 Risks and Uncertainties [Abstract]

Risks and Uncertainties

RISKS AND UNCERTAINTIES

The Company has certain risks and uncertainties that it experiences during volatile market conditions. These volatilities can have a severe impact on operations.  The Company's revenues are derived from the sale and distribution of ethanol, distillers grains, and corn oil to customers primarily located in the United States. Corn for the production process is supplied to our plant primarily from local agricultural producers and from purchases on the open market.  Ethanol sales typically average 80-85% of total revenues and corn costs typically average 70-80% of cost of goods sold.

The Company's operating and financial performance is largely driven by the prices at which they sell ethanol and the net expense of corn. The price of ethanol is influenced by factors such as supply and demand, the weather, government policies and programs, and unleaded gasoline prices and the petroleum markets as a whole. Excess ethanol supply in the market, in particular, puts downward pressure on the price of ethanol. Our largest cost of production is corn.  The cost of corn is generally impacted by factors such as supply and demand, the weather, government policies and programs, and our risk management program used to protect against the price volatility of these commodities.

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Revolving Line of Credit & Long Term Debt Narrative (Details) (USD $)	12 Months Ended		12 Months Ended			12 Months Ended					3 Months Ended	12 Months Ended		3 Months Ended	12 Months Ended					0 Months Ended									3 Months Ended
	Oct. 31, 2013	Oct. 31, 2012	Oct. 31, 2013 Revolving Operating Loan [Member]	Oct. 31, 2013 Compensating Balances, Cash and Cash Equivalents [Domain]	Oct. 31, 2013 Revolving Operating Loan, Net [Member]	Oct. 31, 2013 Revolving Term Loan [Member]	Oct. 31, 2012 Revolving Term Loan [Member]	Jul. 31, 2013 Note Payable at Granite Falls Bank [Member]	Oct. 31, 2013 Heron Lake Bioenergy [Member]	Oct. 31, 2012 Heron Lake Bioenergy [Member]	Jan. 31, 2013 Heron Lake Bioenergy [Member] Revolving Operating Loan [Member]	Oct. 31, 2013 Heron Lake Bioenergy [Member] Revolving Operating Loan [Member]	Oct. 31, 2012 Heron Lake Bioenergy [Member] Revolving Operating Loan [Member]	Jan. 31, 2013 Heron Lake Bioenergy [Member] Revolving Term Loan [Member]	Oct. 31, 2013 Heron Lake Bioenergy [Member] Revolving Term Loan [Member]	Oct. 31, 2012 Heron Lake Bioenergy [Member] Revolving Term Loan [Member]	Oct. 31, 2013 Granite Falls Energy [Member] Revolving Term Loan [Member]	Oct. 31, 2012 Granite Falls Energy [Member] Revolving Term Loan [Member]	Jul. 31, 2013 Project Viking, LLC [Member]	Aug. 30, 2013 Project Viking, LLC [Member] Long-term Debt [Member]	Oct. 31, 2013 Board of Governors [Member]	Oct. 31, 2013 Unit Holders, non-Board of Governors [Member]	Oct. 31, 2013 Minimum [Member] Revolving Operating Loan [Member]	Oct. 31, 2013 Minimum [Member] Revolving Term Loan [Member]	Oct. 31, 2013 Minimum [Member] Heron Lake Bioenergy [Member] Revolving Term Loan [Member]	Oct. 31, 2013 Maximum [Member] Revolving Operating Loan [Member]	Oct. 31, 2013 Maximum [Member] Revolving Term Loan [Member]	Oct. 31, 2013 Maximum [Member] Heron Lake Bioenergy [Member] Revolving Term Loan [Member]	Jan. 31, 2013 Convertible Subordinated Debt [Member]	Jan. 31, 2013 Common Class A [Member] Convertible Subordinated Debt [Member]	Oct. 31, 2013 Common Class A [Member] Convertible Subordinated Debt [Member]
Line of Credit Facility [Line Items]
Long-term Debt	$ 36,472,763			$ 0	$ 5,660,000			$ 5,000,000				$ 20,500,000			$ 17,400,000		$ 18,000,000		$ 4,024,500
Debt Instrument, Interest Rate During Period																				4.00%									7.25%
Line of Credit Facility, Interest Rate Description			"One Month LIBOR Index Rate," plus 265			"One Month LIBOR Index Rate," plus 265									LIBOR plus 3.50% but not less than 5%
Debt Instrument, Basis Spread on Variable Rate																							2.80%	2.80%	3.50%	3.05%	3.05%	5.00%
Letters of Credit Reduction, Amount	49,000					2,000,000					2,000,000
Line of Credit Facility, Amount Outstanding		5,389,588				2,513,674	4,891,952					6,263,158	0		18,317,800	0	2,513,674	4,891,952
Letters of Credit Outstanding, Amount	337,928
Debt Instrument, Amortization Period															10 years
Required Additional Payment of Excess Cash Flow, Percent															25.00%
Required Additional Payment of Excess Cash Flow, Amount														2,000,000
Debt Instrument, Interest Rate, Stated Percentage															5.75%
Long Term Debt, Fee on Unused Borrowing												0.35%
Convertible Subordinated Debt, Noncurrent									4,143,000	0											1,400,000	3,700,000
Debt Instrument, Convertible, Conversion Price																															$ 0.30
Debt Conversion, Converted Instrument, Amount																														$ 934,500
Conversion of Stock, Shares Converted																														3,115,000

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Leases Leases (Tables)

12 Months Ended

Oct. 31, 2013

Leases [Abstract]

Schedule of Future Minimum Rental Payments for Operating Leases [Table Text Block]

At October 31, 2013, the Company had the following commitments for payments of rentals under operating leases which at inception had a non-cancelable term of more than one year:

November 1, 2013 to October 31, 2014	$	2,602,286
November 1, 2014 to October 31, 2015	1,640,775
November 1, 2015 to October 31, 2016	940,910
November 1, 2016 to October 31, 2017	474,004
November 1, 2017 to October 31, 2018	60,816
Total minimum lease commitments	$	5,718,791

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Revolving Line of Credit & Long Term Debt Long Term Debt (Tables)

12 Months Ended

Oct. 31, 2013

Debt Instrument [Line Items]

Schedule of Maturities of Long-term Debt [Table Text Block]

stimated maturities of long-term debt at October 31, 2013 are as follows: 

2014	$	3,490,808
2015	2,846,762
2016	21,602,578
2017	522,563
2018	7,022,813
After 2018	987,239
Total long-term debt	$	36,472,763

Schedule of Long-term Debt Instruments [Table Text Block]

Long-term debt consists of the following:

	October 31, 2013		October 31, 2012
GRANITE FALLS ENERGY:
Capital One Shuttlewagon Railcar Mover (5 year term at 3.875%, due in monthly installments of $10,995)	$	382,918	$	497,636
Revolving Term Loan	2,513,674		4,891,952
HERON LAKE BIOENERGY:
Term note payable to lending institution (including premium of approximately $1.74m)	18,317,800		—
Revolving term note payable to lending institution (including premium of approximately $283k)	6,263,158		—
Assessment payable as part of water treatment agreement, due in semi-annual installments of $189,393 with interest at 6.55%, enforceable by statutory lien, with the final payment due in 2021. The Company made deposits for one years' worth of debt service payments that are held on deposit to be applied with the final payments of the assessment.	2,246,771		—
Assessment payable as part of water treatment agreement, due in semi-annual installments of $25,692 with interest at 0.50%, enforceable by statutory lien, with the final payment due in 2016.	152,698		—
Assessment payable as part of water supply agreement, due in monthly installments of $3,942 with interest at 8.73%, enforceable by statutory lien, with the final payment due in 2019.	205,209		—
Note payable to electrical company with monthly payments of $6,250 with a 1% maintenance fee due each October, due September 2017. The electrical company is a member of the Company.	293,750		—
Note payable to a lending institution for the construction of the pipeline assets initially due in December 2011, converted in February 2012 to a term loan with a three year repayment period. Interest is at 5.29% and the note, along with the line of credit in Note 8, is secured by substantially all assets of Agrinatural.	1,013,132		—
Note payable to noncontrolling interest member of Agrinatural. Interest is at 5.425%, with a maturity date of October 2014.	300,000		—
Equipment payable on corn oil separation equipment from a vendor. The Company pays approximately $40,000 per month conditioned upon revenue generated from the corn oil equipment. The monthly payment includes implicit interest of 5.57% until maturity in May 2015 and the note is secured by the equipment.	640,653		—
Subordinated Convertible Debt with interest of 7.25% paid on a semi-annual basis.	4,143,000		—
Totals	36,472,763		5,389,588
Less amounts due within one year	3,490,808		114,718
Net long-term debt	$	32,981,955	$	5,274,870

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Revolving Line of Credit & Long Term Debt Long Term Debt (Details) (USD $)	12 Months Ended		12 Months Ended												3 Months Ended
	Oct. 31, 2013	Oct. 31, 2012	Oct. 31, 2013 Shuttlewagon Railcar Mover [Member]	Oct. 31, 2013 Revolving Term Loan [Member]	Oct. 31, 2012 Revolving Term Loan [Member]	Oct. 31, 2013 Revolving Operating Loan, Net [Member]	Oct. 31, 2013 Granite Falls Energy [Member]	Oct. 31, 2012 Granite Falls Energy [Member]	Oct. 31, 2013 Granite Falls Energy [Member] Revolving Term Loan [Member]	Oct. 31, 2012 Granite Falls Energy [Member] Revolving Term Loan [Member]	Oct. 31, 2013 Heron Lake Bioenergy [Member]	Oct. 31, 2012 Heron Lake Bioenergy [Member]	Oct. 31, 2013 Heron Lake Bioenergy [Member] Corn Oil Separation [Member]	Oct. 31, 2012 Heron Lake Bioenergy [Member] Corn Oil Separation [Member]	Jan. 31, 2013 Heron Lake Bioenergy [Member] Revolving Operating Loan [Member]	Oct. 31, 2013 Heron Lake Bioenergy [Member] Revolving Operating Loan [Member]	Oct. 31, 2012 Heron Lake Bioenergy [Member] Revolving Operating Loan [Member]	Oct. 31, 2013 Heron Lake Bioenergy [Member] Water Assessment [Member]	Oct. 31, 2012 Heron Lake Bioenergy [Member] Water Assessment [Member]	Oct. 31, 2013 Heron Lake Bioenergy [Member] Revolving Term Loan [Member]	Oct. 31, 2012 Heron Lake Bioenergy [Member] Revolving Term Loan [Member]	Oct. 31, 2013 Heron Lake Bioenergy [Member] Water Treatment Plant [Member]	Oct. 31, 2012 Heron Lake Bioenergy [Member] Water Treatment Plant [Member]	Oct. 31, 2013 Heron Lake Bioenergy [Member] Water Supply [Member]	Oct. 31, 2012 Heron Lake Bioenergy [Member] Water Supply [Member]	Oct. 31, 2013 Heron Lake Bioenergy [Member] Electrical Company [Member]	Oct. 31, 2012 Heron Lake Bioenergy [Member] Electrical Company [Member]	Oct. 31, 2013 Agrinatural, LLC [Member]	Oct. 31, 2012 Agrinatural, LLC [Member]	Oct. 31, 2013 Agrinatural, LLC [Member] Natural Gas Pipeline Construction Loan [Member]	Oct. 31, 2012 Agrinatural, LLC [Member] Natural Gas Pipeline Construction Loan [Member]
Debt Instrument [Line Items]
Long-term Debt, Maturities, Repayments of Principal in Year Two	$ 2,846,762
Shuttlewagon Railcar Mover Loan							382,918	497,636
Letters of Credit Outstanding, Amount	337,928
LOC Term			5
Debt Instrument, Interest Rate, Stated Percentage			3.875%																	5.75%
Long-term Debt	36,472,763					5,660,000			18,000,000							20,500,000				17,400,000
Long-term Debt, Current Maturities	(3,490,808)
Letters of Credit Reduction, Amount	49,000			2,000,000											2,000,000
Long-term Debt, Maturities, Repayments of Principal in Year Three	21,602,578
Long-term Debt, Maturities, Repayments of Principal in Year Four	522,563
Long-term Debt, Maturities, Repayments of Principal in Year Five	7,022,813
Long-term Debt, Maturities, Repayments of Principal after Year Five	987,239
Long-term Debt, less current portion	32,981,955	5,274,870
Line of Credit Facility, Amount Outstanding		5,389,588		2,513,674	4,891,952				2,513,674	4,891,952			640,653	0		6,263,158	0	2,246,771	0	18,317,800	0	152,698	0	205,209	0	293,750	0	300,000	0	1,013,132	0
Current portion long-term debt	3,490,808	114,718
Convertible Subordinated Debt, Noncurrent											$ 4,143,000	$ 0

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Fair Value FMV (Tables)

12 Months Ended

Oct. 31, 2013

Fair Value Disclosures [Abstract]

Fair Value, by Balance Sheet Grouping [Table Text Block]

The acquisition date fair value of the consideration transferred consisted of the following:

Cash	$	8,000,000
Note payable	4,024,500
Assumption of note payable to Granite Falls Bank	5,000,000
Total Consideration	$	17,024,500

The following table provides information on those derivative assets measured at fair value on a recurring basis at October 31, 2013:

	Carrying Amount in Balance Sheet October 31, 2013			Fair Value October 31, 2013			Fair Value Measurement Using
							Quoted Prices in Active Markets (Level 1)			Significant Other Observable Inputs (Level 2)		Significant unobservable inputs (Level 3)
Financial Liabilities:
Derivative Instruments	$	(75,113	)	$	(75,113	)	$	(75,113	)	$	—	$	—

The following table provides information on those derivative assets measured at fair value on a recurring basis at October 31, 2012:

	Carrying Amount in Balance Sheet October 31, 2012			Fair Value October 31, 2012			Fair Value Measurement Using
							Quoted Prices in Active Markets (Level 1)			Significant Other Observable Inputs (Level 2)		Significant unobservable inputs (Level 3)
Financial Liabilities:
Derivative Instruments	$	(45,563	)	$	(45,563	)	$	(45,563	)	$	—	$	—

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Income Taxes (Tables)

12 Months Ended

Oct. 31, 2013

Income Tax Disclosure [Abstract]

Taxable Income Reconciliation [Table Text Block]

The differences between the financial statement basis and tax basis of assets are based on the following:

	October 31, 2013			October 31, 2012
Financial statement basis of assets	$	112,673,222		$	61,133,132
Organization & start-up costs capitalized for tax purposes, net	625,720			715,109
Tax depreciation greater than book depreciation	(24,977,852		)	(25,653,678		)
Unrealized derivatives losses	75,113			45,563
Capitalized inventory	35,761			10,957
Net effect of consolidation of acquired subsidiary	(10,396,697		)	—
Income tax basis of assets	$	78,035,267		$	36,251,083
Financial statement basis of liabilities	$	44,305,219		$	11,277,807
Debt premium - acquisition fair value adjustment	(2,023,441		)	—
Income tax basis of liabilities	$	42,281,778		$	11,277,807

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Summary of Significant Accounting Policies

12 Months Ended

Oct. 31, 2013

Summary of Significant Accounting Policies [Abstract]

Summary of Significant Account Policies

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

Principles of Consolidation

The accompanying consolidated financial statements consolidate the operating results and financial position of Granite Falls Energy, LLC (“GFE” or the “Company”), and its wholly owned subsidiary, Project Viking, L.L.C. ("Project Viking") which owns 60.8% of Heron Lake BioEnergy, LLC (“HLBE”). The remaining 39.2% ownership of HLBE is included in the consolidated financial statements as a non-controlling interest. All intercompany balances and transactions are eliminated in consolidation. The acquisition occurred on July 31, 2013 and therefore the consolidated statements of operations only include the three month period ended October 31, 2013 of HLBE. See Note 3 for details of acquisition.

Nature of Business

GFE is a Minnesota limited liability company currently producing fuel-grade ethanol, distillers grains, and crude corn oil near Granite Falls, Minnesota and sells these products, pursuant to marketing agreements, throughout the continental United States and on the international market. GFE's plant has an approximate annual production capacity of 60 million gallons, but is currently permitted to produce up to 70 million gallons of undenatured ethanol on a twelve month rolling sum basis.

HLBE is a Minnesota limited liability company currently producing fuel-grade ethanol, distillers grains, and crude corn oil near Heron Lake, Minnesota and sells these products, pursuant to marketing agreements, throughout the continental United States. HLBE's plant has an approximate annual production capacity of 55 million gallons, but is currently permitted to produce up to 59.2 million gallons.

Fiscal Reporting Period

The Company has adopted a fiscal year ending October 31 for financial reporting purposes.

Accounting Estimates

Management uses estimates and assumptions in preparing these financial statements in accordance with generally accepted accounting principles in the United States of America. 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. The Company uses estimates and assumptions in accounting for the following significant matters, among others: economic lives of property, plant, and equipment, valuation of commodity derivatives and inventory, and the assumptions used in the impairment analysis of long-lived assets and the assumptions used to estimate the fair value of acquired assets and liabilities, which includes goodwill. Actual results may differ from previously estimated amounts, and such differences may be material to our financial statements. The Company periodically reviews estimates and assumptions, and the effects of revisions are reflected in the period in which the revision is made.

Cash

The Company maintains its accounts primarily at two financial institutions, of which one is a member of the Company. At times throughout the year, the Company's cash balances may exceed amounts insured by the Federal Deposit Insurance Corporation. The Company does not believe it is exposed to any significant credit risk on its cash balances.

Restricted Cash

The Company has restricted cash balances relating to its margin requirements with the Company's commodity derivative broker based on open commodity contracts discussed in Note 5.

Accounts Receivable

Credit terms are extended to customers in the normal course of business. The Company performs ongoing credit evaluations of its customers' financial condition and, generally, requires no collateral.

Accounts receivable are recorded at their estimated net realizable value. Accounts are considered past due if payment is not made on a timely basis in accordance with the Company's credit terms. Accounts considered uncollectible are written off. The Company follows a policy of providing an allowance for doubtful accounts; however, based on historical experience, and its evaluation of the current status of receivables, the Company is of the belief that such accounts will be collectible in all material respects and thus an allowance was not necessary at October 31, 2013 or 2012. It is at least possible this estimate will change in the future.

Inventory

Inventory is stated at the lower of cost or market. Cost for all inventories is determined using the first in first out method (FIFO). Market is based on current replacement values except that it does not exceed net realizable values and it is not less than net realizable values reduced by allowances from normal profit margin. Inventory consists of raw materials, work in process, finished goods, and spare parts. Corn is the primary raw material along with other raw materials. Finished goods consist of ethanol, distillers grains, and corn oil.

Property, Plant, and Equipment

Property, plant, and equipment are stated at cost. Depreciation is provided over the following estimated useful lives by use of the straight-line method.

Asset Description	Years
Land improvements	5-20 years
Buildings	10-30 years
Grain handling equipment	5-15 years
Mechanical equipment	5-15 years
Equipment	5-10 years

Maintenance and repairs are expensed as incurred; major improvements and betterments are capitalized.  Construction in progress expenditures will be depreciated using the straight-line method over their estimated useful lives once the assets are placed into service. Depreciation expense totaled approximately $5,937,000, $4,161,000, and $3,979,000 for the fiscal years ended October 31, 2013, 2012, and 2011, respectively.

Long-Lived Assets

Long-lived assets, such as property, plant, and equipment, and purchased intangible assets subject to amortization, are reviewed for impairment whenever events or changes in circumstances indicate that the carrying amount of an asset may not be recoverable. If circumstances require a long-lived asset be tested for possible impairment, the Company first compares undiscounted cash flows expected to be generated by an asset to the carrying value of the asset. If the carrying value of the long-lived asset is not recoverable on an undiscounted cash flow basis, impairment is recognized to the extent that the carrying value exceeds its fair value. Fair value is determined through various valuation techniques including, but not limited to, discounted cash flow models, quoted market values and third-party independent appraisals, as considered necessary. No indicators of impairment existed during fiscal 2013 or 2012 that would have triggered impairment testing, and therefore, no impairment expense was recorded during 2013 or 2012.

Revenue Recognition

The Company generally sells ethanol and related products pursuant to marketing agreements. Revenues from the production of ethanol and the related products are recorded when the customer has taken title and assumed the risks and rewards of ownership, prices are fixed or determinable and collectability is reasonably assured. Ethanol and related products are generally shipped free on board (FOB) shipping point. The Company believes there are no ethanol sales, during any given month, which should be considered contingent and recorded as deferred revenue.

In accordance with the Company's agreements for the marketing and sale of ethanol and related products, marketing fees and commissions due to the marketers are deducted from the gross sales price as earned. These fees and commissions are recorded net of revenues, as they do not provide an identifiable benefit that is sufficiently separable from the sale of ethanol and related products. Shipping costs paid by the Company to the marketer in the sale of ethanol are not specifically identifiable and, as a result, are recorded based on the net selling price reported to the Company from the marketer. Shipping costs incurred by the Company in the sale of distillers grains and corn oil are included in cost of goods sold.

Fair Value of Financial Instruments

The Company's accounting for fair value measurements of assets and liabilities that are recognized or disclosed at fair value in the financial statements on a recurring or nonrecurring basis adhere to the Financial Accounting Standards Board (FASB) fair value hierarchy that prioritizes the inputs to valuation techniques used to measure fair value. The Company has adopted guidance for fair value measurement related to nonfinancial items that are recognized and disclosed at fair value in the financial statements on a nonrecurring basis. The guidance establishes a fair value hierarchy that prioritizes the inputs to valuation techniques used to measure fair value. The hierarchy gives the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities (Level 1 measurements) and the lowest priority to measurements involving significant unobservable inputs (Level 3 measurements).

The three levels of the fair value hierarchy are as follows:

• Level 1 inputs are quoted prices (unadjusted) in active markets for identical assets or liabilities that the Company has the ability to access at the measurement date.

• Level 2 inputs are inputs other than quoted prices included within Level 1 that are observable for the asset or liability, either directly or indirectly, for substantially the full term of the asset or liability.

• Level 3 inputs are unobservable inputs for the asset or liability.

The level in the fair value hierarchy within which a fair measurement in its entirety falls is based on the lowest level input that is significant to the fair value measurement in its entirety.

Except for those assets and liabilities which are required by authoritative accounting guidance to be recorded at fair value in our balance sheets, the Company has elected not to record any other assets or liabilities at fair value. No events occurred during the fiscal years ended October 31, 2013 or 2012 that required adjustment to the recognized balances of assets or liabilities, which are recorded at fair value on a nonrecurring basis.

The carrying value of cash, restricted cash, accounts receivable, accounts payable and accrued liabilities approximates fair value due to the short maturity of these instruments. The Company obtains fair value measurements from an independent pricing service for corn derivative contracts.  The fair value measurements consider observable data that may include dealer quotes and live trading levels from the Chicago Board of Trade and New York Mercantile Exchange markets. The fair value of the long-term debt is estimated based on anticipated interest rates which management believes would currently be available to the Company for similar issues of debt, taking into account the current credit risk of the Company and other market factors. The Company believes the carrying value of the debt instruments approximate fair value.

Derivative Instruments

From time to time the Company enters into derivative transactions to hedge its exposures to commodity price fluctuations. The Company is required to record these derivatives in the balance sheets at fair value.

In order for a derivative to qualify as a hedge, specific criteria must be met and appropriate documentation maintained. Gains and losses from derivatives that do not qualify as hedges, or are undesignated, must be recognized immediately in earnings. If the derivative does qualify as a hedge, depending on the nature of the hedge, changes in the fair value of the derivative will be either offset against the change in fair value of the hedged assets, liabilities, or firm commitments through earnings or recognized in other comprehensive income until the hedged item is recognized in earnings. Changes in the fair value of undesignated derivatives are recorded in earnings.

Additionally, the Company is required to evaluate its contracts to determine whether the contracts are derivatives. Certain contracts that literally meet the definition of a derivative may be exempted 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 accounting and reporting requirements, and therefore, are not marked to market in our financial statements.

In order to reduce the risks caused by market fluctuations, the Company occasionally hedges its anticipated corn, natural gas, and denaturant purchases and ethanol sales by entering into options and futures contracts. These contracts are used with the intention to fix the purchase price of anticipated requirements for corn in the Company's ethanol production activities and the related sales price of ethanol. The fair value of these contracts is based on quoted prices in active exchange-traded or over-the-counter market conditions. Although the Company believes its commodity derivative positions are economic hedges, none have been formally designated as a hedge for accounting purposes and derivative positions are recorded on the balance sheet at their fair market value, with changes in fair value recognized in current period earnings or losses. The Company does not enter into financial instruments for trading or speculative purposes.

The Company has adopted authoritative guidance related to “Derivatives and Hedging,” and has included the required enhanced quantitative and qualitative disclosure about objectives and strategies for using derivatives, quantitative disclosures about fair value amounts of gains and losses from derivative instruments, and disclosures about credit-risk-related contingent features in derivative agreements. See further discussion in Note 5.

Income Taxes

The Company is treated as a partnership for federal and state income tax purposes, and generally does not incur income taxes. Instead its earnings and losses are included in the income tax returns of its members. Therefore, no provision or liability for federal or state income taxes has been included in these financial statements. The Company had no significant uncertain tax positions as of October 31, 2013 or 2012. For years before fiscal 2011, the Company is no longer subject to U.S. Federal or state income tax examinations.

Environmental Liabilities

The Company's operations are subject to environmental laws and regulations adopted by various governmental entities 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 location. 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 liability is probable and the costs can be reasonably estimated. No expense has been recorded for the fiscal years ended October 31, 2013, 2012, or 2011.

Net Income per Unit

Basic net income per unit is computed by dividing net income by the weighted average number of members' units outstanding during the period. 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, for all periods presented, the calculations of the Company's basic and diluted net income per unit are the same.

Business Combinations

The Company allocates the total purchase price of a business combination to the assets acquired and the liabilities assumed based on their estimated fair values at the acquisition date, with the excess purchase price recorded as goodwill. The Company used current market data to assist them in determining the fair value of the assets acquired and liabilities assumed, including goodwill, based on recognized business valuation methodology. Subsequent to the acquisition but not to exceed one year from the acquisition date, the Company will record any material adjustments retrospectively to the initial estimate based on new information obtained about facts and circumstances that existed as of the acquisition date. The Company expenses any acquisition-related costs as incurred in connection with business combinations. An income, market or cost valuation method may be utilized to estimate the fair value of the assets acquired or liabilities assumed in a business combination. The income valuation method represents the present value of future cash flows over the life of the asset using (i) discrete financial forecasts, which rely on management's estimates of revenue and operating expenses, (ii) long-term growth rates, and (iii) an appropriate discount rate. The market valuation method uses prices paid for a reasonably similar asset by other purchasers in the market, with adjustments relating to any differences between the assets. The cost valuation method is based on the replacement cost of a comparable asset at prices at the time of the acquisition reduced for depreciation of the asset.

Goodwill

Goodwill represents the cost in excess of the fair value of net assets acquired. The Company conducts impairment assessments annually or when events indicate a triggering event has occurred.

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Quarterly Financial Data (Unaudited) Quarterly Financials (Tables)

12 Months Ended

Oct. 31, 2013

Quarterly Financial Information Disclosure [Abstract]

Schedule of Quarterly Financial Information [Table Text Block]

Summary quarterly results are as follows:

	First Quarter		Second Quarter		Third Quarter		Fourth Quarter
Fiscal year ended October 31, 2013
Revenues	$	47,117,122	$	48,020,602	$	48,884,076	$	80,079,134
Gross profit	832,144		3,629,972		2,710,179		6,581,018
Operating income	269,449		3,047,007		2,197,158		5,521,116
Net income attributable to GFE	221,427		3,031,943		2,173,701		4,874,950
Basic and diluted earnings per unit attributable to GFE	7.23		99.06		71.02		159.31

	First Quarter		Second Quarter		Third Quarter			Fourth Quarter
Fiscal year ended October 31, 2012
Revenues	$	43,745,776	$	39,025,122	$	42,435,763		$	49,955,382
Gross profit (loss)	3,687,950		657,416		54,694			(1,946,091		)
Operating income (loss)	3,024,214		66,935		(597,187		)	(2,489,589		)
Net income (loss)	3,042,288		116,466		(565,637		)	(2,432,510		)
Basic and diluted earnings (loss) per unit	99.29		3.81		(18.49		)	(79.36		)

	First Quarter		Second Quarter		Third Quarter		Fourth Quarter
Fiscal year ended October 31, 2011
Revenues	$	30,716,346	$	34,537,750	$	45,414,923	$	45,852,470
Gross profit	3,533,733		3,704,535		2,068,381		4,861,424
Operating income	2,975,612		3,245,729		1,550,481		4,393,545
Net income	3,011,596		3,270,110		1,586,882		4,423,268
Basic and diluted earnings per unit	98.24		106.67		51.76		144.29

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Derivative Instruments Narrative (Details) (USD $)	Oct. 31, 2013	Oct. 31, 2012
Margin requirements [Member]
Derivative [Line Items]
Restricted Cash and Cash Equivalents, Current	$ 393,750	$ 494,000
Corn Contracts [Member]
Derivative [Line Items]
Outstanding corn derivative instrument	1,125,000	1,235,000

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Balance Sheets (USD $)	Oct. 31, 2013	Oct. 31, 2012
Current Assets
Cash	$ 1,158,774	$ 685,828
Restricted cash	393,750	494,000
Accounts receivable	6,450,694	7,356,534
Inventory	12,370,277	12,013,169
Commodity derivative instruments	0	0
Prepaid expenses and other current assets	1,096,483	165,519
Total current assets	21,469,978	20,715,050
Property, Plant and Equipment
Land and improvements	12,307,063	7,095,172
Railroad improvements	8,005,523	4,121,148
Process equipment and tanks	110,440,407	64,678,860
Administration building	1,015,361	279,734
Office equipment	265,792	154,072
Rolling stock	1,691,857	1,305,395
Construction in progress	2,067,213	3,831,263
Property, Plant and Equipment, Gross	135,793,216	81,465,644
Less accumulated depreciation	46,984,361	41,047,562
Net property, plant and equipment	88,808,855	40,418,082
Goodwill	1,372,473	0
Other Assets	1,021,916	0
Total Assets	112,673,222	61,133,132
Current Liabilities
Current portion long-term debt	3,490,808	114,718
Accounts payable	3,058,633	3,527,840
Corn payable to FCE - related party	4,001,852	1,995,997
Commodity derivative instruments	75,113	45,563
Accrued liabilities	696,858	318,819
Total current liabilities	11,323,264	6,002,937
Long-term Debt, less current portion	32,981,955	5,274,870
Commitments and Contingencies
Members' Equity, 30,656 units authorized, issued and outstanding	59,887,346	49,855,325
Stockholders' Equity Attributable to Noncontrolling Interest	8,480,657	0
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	68,368,003	49,855,325
Total Liabilities and Members’ Equity	$ 112,673,222	$ 61,133,132

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Leases Narrative (Details) (USD $)	3 Months Ended	12 Months Ended
	Oct. 31, 2013	Oct. 31, 2013	Oct. 31, 2012	Oct. 31, 2011
Operating Leases, Future Minimum Payments Due, Next Twelve Months	$ 2,602,286	$ 2,602,286
Operating Leases, Future Minimum Payments, Due in Two Years	1,640,775	1,640,775
Operating Leases, Future Minimum Payments, Due in Three Years	940,910	940,910
Operating Leases, Future Minimum Payments, Due in Four Years	474,004	474,004
Operating Leases, Future Minimum Payments, Due in Five Years	60,816	60,816
Operating Leases, Future Minimum Payments Due	5,718,791	5,718,791
Operating Leases, Rent Expense		1,800,000	2,200,000	1,800,000
Hopper Cars [Member]
Operating Leases, Rent Expense, Net		75
Rail Cars [Member]
Operating Leases, Rent Expense, Net		176
Hopper Cars [Member]
Operating Leases, Rent Expense, Net		620
Rail Cars [Member]
Operating Leases, Rent Expense, Net		121,000
Hopper Cars [Member]
Operating Leases, Rent Expense, Net		0.03
Hopper Cars [Member]
Operating Leases, Rent Expense, Net		36,000
Rail Cars [Member]
Operating Leases, Rent Expense, Net		1,437,000	1,278,000	1,171,000
Hopper Cars [Member]
Operating Leases, Rent Expense, Net		557,000	552,000	553,000
Contract Length	5 years
Carrying (Reported) Amount, Fair Value Disclosure [Member]
Derivative Liabilities	(75,113)	(75,113)	(45,563)
Fair Value, Measurements, Recurring [Member]
Derivative Liabilities	(75,113)	(75,113)	(45,563)
Fair Value, Inputs, Level 1 [Member]
Derivative Liabilities	(75,113)	(75,113)	(45,563)
Fair Value, Inputs, Level 2 [Member]
Derivative Liabilities	0	0	0
Fair Value, Inputs, Level 3 [Member]
Derivative Liabilities	$ 0	$ 0	$ 0

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Statement of Changes in Members' Equity parenthetical (USD $)	12 Months Ended
	Oct. 31, 2013
Noncontrolling Interest, Decrease from Distributions to Noncontrolling Interest Holders	$ (38,336)
Stock Repurchased During Period, Shares	50
Noncontrolling Interest [Member]
Noncontrolling Interest, Decrease from Distributions to Noncontrolling Interest Holders	$ (38,336)

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Summary of Significant Accounting Policies Depreciation Expense (Details) (USD $)	12 Months Ended
	Oct. 31, 2013	Oct. 31, 2012	Oct. 31, 2011
Real Estate and Accumulated Depreciation [Line Items]
Depreciation	$ 5,937,000	$ 4,161,000	$ 3,979,000

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Quarterly Financial Data (Unaudited)

12 Months Ended

Oct. 31, 2013

Quarterly Financial Data (Unaudited) [Abstract]

Quarterly Financial Data (Unaudited)

QUARTERLY FINANCIAL DATA (UNAUDITED)

Summary quarterly results are as follows:

	First Quarter		Second Quarter		Third Quarter		Fourth Quarter
Fiscal year ended October 31, 2013
Revenues	$	47,117,122	$	48,020,602	$	48,884,076	$	80,079,134
Gross profit	832,144		3,629,972		2,710,179		6,581,018
Operating income	269,449		3,047,007		2,197,158		5,521,116
Net income attributable to GFE	221,427		3,031,943		2,173,701		4,874,950
Basic and diluted earnings per unit attributable to GFE	7.23		99.06		71.02		159.31

	First Quarter		Second Quarter		Third Quarter			Fourth Quarter
Fiscal year ended October 31, 2012
Revenues	$	43,745,776	$	39,025,122	$	42,435,763		$	49,955,382
Gross profit (loss)	3,687,950		657,416		54,694			(1,946,091		)
Operating income (loss)	3,024,214		66,935		(597,187		)	(2,489,589		)
Net income (loss)	3,042,288		116,466		(565,637		)	(2,432,510		)
Basic and diluted earnings (loss) per unit	99.29		3.81		(18.49		)	(79.36		)

	First Quarter		Second Quarter		Third Quarter		Fourth Quarter
Fiscal year ended October 31, 2011
Revenues	$	30,716,346	$	34,537,750	$	45,414,923	$	45,852,470
Gross profit	3,533,733		3,704,535		2,068,381		4,861,424
Operating income	2,975,612		3,245,729		1,550,481		4,393,545
Net income	3,011,596		3,270,110		1,586,882		4,423,268
Basic and diluted earnings per unit	98.24		106.67		51.76		144.29

The above quarterly financial data is unaudited, but in the opinion of management, all adjustments necessary for a fair presentation of the selected data for these periods presented have been included.

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Risks and Uncertainties Narrative (Details)	Oct. 31, 2013
Minimum [Member]
Concentration Risk [Line Items]
Sales Revenue, Goods, Net, Percentage	80.00%
Minimum [Member] | Corn Contracts [Member]
Concentration Risk [Line Items]
Percent of Cost of Goods Sold	70.00%
Maximum [Member]
Concentration Risk [Line Items]
Sales Revenue, Goods, Net, Percentage	85.00%
Percent of Cost of Goods Sold	80.00%

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Summary of Significant Accounting Policies Summary of Significant Accounting Policies (Tables)

12 Months Ended

Oct. 31, 2013

Accounting Policies [Abstract]

Property, Plant and Equipment [Table Text Block]

Property, plant, and equipment are stated at cost. Depreciation is provided over the following estimated useful lives by use of the straight-line method.

Asset Description	Years
Land improvements	5-20 years
Buildings	10-30 years
Grain handling equipment	5-15 years
Mechanical equipment	5-15 years
Equipment	5-10 years

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Statements of Cash Flows (USD $)	12 Months Ended
	Oct. 31, 2013	Oct. 31, 2012	Oct. 31, 2011
Cash Flows from Operating Activities
Net Income (Loss)	$ 10,032,021	$ 160,607	$ 12,291,856
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest	10,558,773	160,607	12,291,856
Adjustments to reconcile net income to net cash provided by operations:
Depreciation and amortization	5,549,204	4,161,021	3,988,606
Change in fair value of derivative instruments	(155,563)	1,651,799	(1,271,242)
Change in operating assets and liabilities
Restricted cash	611,205	1,009,000	(601,500)
Commodity derivative instruments	185,113	(1,202,186)	1,619,692
Accounts receivable	3,910,961	(3,578,987)	(613,338)
Inventory	1,946,049	(3,397,758)	(4,284,741)
Prepaid expenses and other current assets	176,061	12,274	(60,904)
Accounts payable	(5,995)	286,878	871,671
Accrued liabilities	(59,920)	(56,606)	(60,514)
Net Cash Provided by Operating Activities	22,715,888	(953,958)	11,879,586
Cash Flows from Investing Activities
Proceeds from (payments for) short-term investments	0	0	3,500,000
Payments for capital expenditures	(2,636,048)	(4,083,943)	(3,550,020)
Payments for construction in process	540,000	0	0
Proceeds from sale of equipment	0	(3,467,199)	0
Payments to Acquire Businesses, Net of Cash Acquired	(6,977,236)	0	0
Net Cash Used in Investing Activities	(9,073,284)	(7,551,142)	(50,020)
Cash Flows from Financing Activities
Payments on revolving line of credit	0	5,490,926	0
Payments on long-term debt	(16,840,158)	(101,338)	(232,431)
Restricted cash	3,670,500	0	0
Payments for Repurchase of Common Stock	0	(66,420)	0
Member distributions paid	0	(9,196,800)	(9,196,800)
Net Cash Used in Financing Activities	(13,169,658)	(3,873,632)	(9,429,231)
Net Increase in Cash	472,946	(12,378,732)	2,400,335
Cash - Beginning of Period	685,828	13,064,560	10,664,225
Cash - End of Period	1,158,774	685,828	13,064,560
Cash paid during the period for:
Interest Expense	388,306	44,002	6,857
Supplemental Disclosure of Noncash Investing and Financing Activities
Conversion of subsidiary subordinated convertible notes	934,500	0	0
Distributions to non-controlling interest in accrued expenses	38,336	0	0
Member distributions included in distributions payable	0	0	9,196,800
Capital expenditures included in accounts payable	$ 605,750	$ 1,129,000	$ 0

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Balance Sheets (Parenthetical)	Oct. 31, 2013	Oct. 31, 2012
Common Stock, Shares Authorized	30,606	30,656
Common Stock, Shares, Issued	30,606	30,656
Common stock, shares outstanding	30,606	30,656

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Employee Benefit Plans

12 Months Ended

Oct. 31, 2013

Employee Benefit Plans [Abstract]

Employee Benefit Plans

EMPLOYEE BENEFIT PLANS

The Company has a defined contribution plan available to all of its qualified employees. The Company contributes a match of 50% of the participant's salary deferral up to a maximum of 3% of the employee's salary. Company contributions totaled approximately $50,000, $51,000, and $46,000 for the fiscal years ended October 31, 2013, 2012, and 2011, respectively.

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Document and Entity Information Document (USD $)	12 Months Ended
	Oct. 31, 2013	Jan. 29, 2014	Apr. 30, 2013
Document Information [Line Items]
Entity Registrant Name	Granite Falls Energy, LLC
Entity Central Index Key	0001181749
Current Fiscal Year End Date	--10-31
Entity Filer Category	Non-accelerated Filer
Document Type	10-K
Document Period End Date	Oct. 31, 2013
Document Fiscal Year Focus	2013
Document Fiscal Period Focus	FY
Amendment Flag	false
Entity Common Stock, Shares Outstanding		30,606
Entity Well-known Seasoned Issuer	No
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Public Float			$ 21,185,000

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Income Taxes

12 Months Ended

Oct. 31, 2013

Income Taxes [Abstract]

Income Tax

INCOME TAXES

The differences between the financial statement basis and tax basis of assets are based on the following:

	October 31, 2013			October 31, 2012
Financial statement basis of assets	$	112,673,222		$	61,133,132
Organization & start-up costs capitalized for tax purposes, net	625,720			715,109
Tax depreciation greater than book depreciation	(24,977,852		)	(25,653,678		)
Unrealized derivatives losses	75,113			45,563
Capitalized inventory	35,761			10,957
Net effect of consolidation of acquired subsidiary	(10,396,697		)	—
Income tax basis of assets	$	78,035,267		$	36,251,083
Financial statement basis of liabilities	$	44,305,219		$	11,277,807
Debt premium - acquisition fair value adjustment	(2,023,441		)	—
Income tax basis of liabilities	$	42,281,778		$	11,277,807

There were no material differences between the financial statement basis and tax basis of the Company's liabilities.

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Statements of Operations (USD $)	12 Months Ended
	Oct. 31, 2013	Oct. 31, 2012	Oct. 31, 2011
Revenues	$ 224,100,934	$ 175,162,043	$ 156,521,489
Cost of Goods Sold - primarily related party	210,077,621	172,708,074	142,353,416
Gross Profit	14,023,313	2,453,969	14,168,073
Operating Expenses	2,988,583	2,449,596	2,002,706
Operating Income	11,034,730	4,373	12,165,367
Other Income (Expense)
Other income (expense)	(48,373)	182,186	37,281
Interest income	813	18,050	93,566
Interest expense	(428,397)	(44,002)	(4,358)
Total other income (expense), net	(475,957)	156,234	126,489
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest	10,558,773	160,607	12,291,856
Net Income (Loss) Attributable to Noncontrolling Interest	526,752	0	0
Net Income	$ 10,032,021	$ 160,607	$ 12,291,856
Weighted Average Units Outstanding - Basic and Diluted	30,606	30,614	30,656
Net Income Per Unit - Basic and Diluted	$ 327.78	$ 5.25	$ 400.96
Distributions Per Unit	$ 0	$ 0.00	$ 600.00

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Derivative Instruments

12 Months Ended

Oct. 31, 2013

Derivative [Line Items]

Derivative Instruments and Hedging Activities Disclosure [Text Block]

DERIVATIVE INSTRUMENTS

As of October 31, 2013, the total notional amount of the Company's outstanding corn derivative instruments was approximately 1,125,000 bushels that were entered into to hedge forecasted corn purchases through December 2013. There may be offsetting positions that are not shown on a net basis that could lower the notional amount of positions outstanding as disclosed above.

The following tables provide details regarding the Company's derivative instruments at October 31, 2013, none of which were designated as hedging instruments:

	Balance Sheet location	Assets		Liabilities
Corn contracts	Commodity derivative instruments	$	—	$	(75,113	)
Totals		$	—	$	(75,113	)

In addition, as of October 31, 2013 the Company maintained $393,750 of restricted cash related to margin requirements for the Company's commodity derivative instrument positions.

As of October 31, 2012, the total notional amount of the Company's outstanding corn derivative instruments was approximately 1,235,000 bushels that were entered into to hedge forecasted corn purchases through March 2013. There may be offsetting positions that are not shown on a net basis that could lower the notional amount of positions outstanding as disclosed above.

The following tables provide details regarding the Company's derivative instruments at October 31, 2012, none of which were designated as hedging instruments:

	Balance Sheet location	Assets		Liabilities
Corn contracts	Commodity derivative instruments	$	—	$	(45,563	)
Totals		$	—	$	(45,563	)

In addition, as of October 31, 2012 the Company maintained approximately $494,000 of restricted cash related to margin requirements for the Company's derivative instrument positions.

The following tables provide details regarding the gains and (losses) from Company's derivative instruments in statements of operations, none of which are designated as hedging instruments:

	Statement of	Fiscal Years Ended October 31,
	Operations location	2013		2012			2011
Ethanol contracts	Revenue	$	—	$	—		$	(4,626	)
Corn contracts	Cost of Goods Sold	155,563		(1,651,799		)	1,280,413
Natural gas contracts	Cost of Goods Sold	—		—			(4,545		)
Total gain (loss)		$	155,563	$	(1,651,799	)	$	1,271,242

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Inventory

12 Months Ended

Oct. 31, 2013

Inventory [Abstract]

Inventory

INVENTORY

Inventories consist of the following:

	October 31, 2013		October 31, 2012
Raw materials	$	4,652,465	$	8,977,820
Spare parts	1,636,466		584,011
Work in process	1,643,574		1,150,239
Finished goods	4,437,772		1,557,546
Totals	$	12,370,277	$	12,013,169

The Company performs a lower of cost or market analysis on inventory to determine if the market values of certain inventories are less than their carrying value, which is attributable primarily to decreases in market prices of corn and ethanol. Based on the lower of cost or market analysis, the Company did not record a lower of cost or market charge on certain inventories for the fiscal years ended October 31, 2013 or 2011. The Company recorded a lower of cost or market charge on certain inventories for the fiscal year ended October 31, 2012 for approximately $77,000.

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Summary of Significant Accounting Policies Summary of Significant Accounting Policies (Policies)

12 Months Ended

Oct. 31, 2013

Accounting Policies [Abstract]

Nature of Business [Policy Text Block]

Nature of Business

GFE is a Minnesota limited liability company currently producing fuel-grade ethanol, distillers grains, and crude corn oil near Granite Falls, Minnesota and sells these products, pursuant to marketing agreements, throughout the continental United States and on the international market. GFE's plant has an approximate annual production capacity of 60 million gallons, but is currently permitted to produce up to 70 million gallons of undenatured ethanol on a twelve month rolling sum basis.

HLBE is a Minnesota limited liability company currently producing fuel-grade ethanol, distillers grains, and crude corn oil near Heron Lake, Minnesota and sells these products, pursuant to marketing agreements, throughout the continental United States. HLBE's plant has an approximate annual production capacity of 55 million gallons, but is currently permitted to produce up to 59.2 million gallons.

Fiscal Period, Policy [Policy Text Block]

Fiscal Reporting Period

The Company has adopted a fiscal year ending October 31 for financial reporting purposes.

Use of Estimates, Policy [Policy Text Block]

Accounting Estimates

Management uses estimates and assumptions in preparing these financial statements in accordance with generally accepted accounting principles in the United States of America. 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. The Company uses estimates and assumptions in accounting for the following significant matters, among others: economic lives of property, plant, and equipment, valuation of commodity derivatives and inventory, and the assumptions used in the impairment analysis of long-lived assets and the assumptions used to estimate the fair value of acquired assets and liabilities, which includes goodwill. Actual results may differ from previously estimated amounts, and such differences may be material to our financial statements. The Company periodically reviews estimates and assumptions, and the effects of revisions are reflected in the period in which the revision is made.

Cash and Cash Equivalents, Policy [Policy Text Block]

Cash

The Company maintains its accounts primarily at two financial institutions, of which one is a member of the Company. At times throughout the year, the Company's cash balances may exceed amounts insured by the Federal Deposit Insurance Corporation. The Company does not believe it is exposed to any significant credit risk on its cash balances.

Cash and Cash Equivalents, Restricted Cash and Cash Equivalents, Policy [Policy Text Block]

Restricted Cash

The Company has restricted cash balances relating to its margin requirements with the Company's commodity derivative broker based on open commodity contracts discussed in Note 5.

Receivables, Policy [Policy Text Block]

Accounts Receivable

Credit terms are extended to customers in the normal course of business. The Company performs ongoing credit evaluations of its customers' financial condition and, generally, requires no collateral.

Accounts receivable are recorded at their estimated net realizable value. Accounts are considered past due if payment is not made on a timely basis in accordance with the Company's credit terms. Accounts considered uncollectible are written off. The Company follows a policy of providing an allowance for doubtful accounts; however, based on historical experience, and its evaluation of the current status of receivables, the Company is of the belief that such accounts will be collectible in all material respects and thus an allowance was not necessary at October 31, 2013 or 2012. It is at least possible this estimate will change in the future.

Inventory, Policy [Policy Text Block]

Inventory

Inventory is stated at the lower of cost or market. Cost for all inventories is determined using the first in first out method (FIFO). Market is based on current replacement values except that it does not exceed net realizable values and it is not less than net realizable values reduced by allowances from normal profit margin. Inventory consists of raw materials, work in process, finished goods, and spare parts. Corn is the primary raw material along with other raw materials. Finished goods consist of ethanol, distillers grains, and corn oil.

Property, Plant and Equipment, Policy [Policy Text Block]

Property, Plant, and Equipment

Property, plant, and equipment are stated at cost. Depreciation is provided over the following estimated useful lives by use of the straight-line method.

Asset Description	Years
Land improvements	5-20 years
Buildings	10-30 years
Grain handling equipment	5-15 years
Mechanical equipment	5-15 years
Equipment	5-10 years

Maintenance and repairs are expensed as incurred; major improvements and betterments are capitalized.  Construction in progress expenditures will be depreciated using the straight-line method over their estimated useful lives once the assets are placed into service. Depreciation expense totaled approximately $5,937,000, $4,161,000, and $3,979,000 for the fiscal years ended October 31, 2013, 2012, and 2011, respectively.

Impairment or Disposal of Long-Lived Assets, Policy [Policy Text Block]

Long-Lived Assets

Long-lived assets, such as property, plant, and equipment, and purchased intangible assets subject to amortization, are reviewed for impairment whenever events or changes in circumstances indicate that the carrying amount of an asset may not be recoverable. If circumstances require a long-lived asset be tested for possible impairment, the Company first compares undiscounted cash flows expected to be generated by an asset to the carrying value of the asset. If the carrying value of the long-lived asset is not recoverable on an undiscounted cash flow basis, impairment is recognized to the extent that the carrying value exceeds its fair value. Fair value is determined through various valuation techniques including, but not limited to, discounted cash flow models, quoted market values and third-party independent appraisals, as considered necessary. No indicators of impairment existed during fiscal 2013 or 2012 that would have triggered impairment testing, and therefore, no impairment expense was recorded during 2013 or 2012.

Revenue Recognition, Policy [Policy Text Block]

Revenue Recognition

The Company generally sells ethanol and related products pursuant to marketing agreements. Revenues from the production of ethanol and the related products are recorded when the customer has taken title and assumed the risks and rewards of ownership, prices are fixed or determinable and collectability is reasonably assured. Ethanol and related products are generally shipped free on board (FOB) shipping point. The Company believes there are no ethanol sales, during any given month, which should be considered contingent and recorded as deferred revenue.

In accordance with the Company's agreements for the marketing and sale of ethanol and related products, marketing fees and commissions due to the marketers are deducted from the gross sales price as earned. These fees and commissions are recorded net of revenues, as they do not provide an identifiable benefit that is sufficiently separable from the sale of ethanol and related products. Shipping costs paid by the Company to the marketer in the sale of ethanol are not specifically identifiable and, as a result, are recorded based on the net selling price reported to the Company from the marketer. Shipping costs incurred by the Company in the sale of distillers grains and corn oil are included in cost of goods sold.

Fair Value of Financial Instruments, Policy [Policy Text Block]

Fair Value of Financial Instruments

The Company's accounting for fair value measurements of assets and liabilities that are recognized or disclosed at fair value in the financial statements on a recurring or nonrecurring basis adhere to the Financial Accounting Standards Board (FASB) fair value hierarchy that prioritizes the inputs to valuation techniques used to measure fair value. The Company has adopted guidance for fair value measurement related to nonfinancial items that are recognized and disclosed at fair value in the financial statements on a nonrecurring basis. The guidance establishes a fair value hierarchy that prioritizes the inputs to valuation techniques used to measure fair value. The hierarchy gives the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities (Level 1 measurements) and the lowest priority to measurements involving significant unobservable inputs (Level 3 measurements).

The three levels of the fair value hierarchy are as follows:

• Level 1 inputs are quoted prices (unadjusted) in active markets for identical assets or liabilities that the Company has the ability to access at the measurement date.

• Level 2 inputs are inputs other than quoted prices included within Level 1 that are observable for the asset or liability, either directly or indirectly, for substantially the full term of the asset or liability.

• Level 3 inputs are unobservable inputs for the asset or liability.

The level in the fair value hierarchy within which a fair measurement in its entirety falls is based on the lowest level input that is significant to the fair value measurement in its entirety.

Except for those assets and liabilities which are required by authoritative accounting guidance to be recorded at fair value in our balance sheets, the Company has elected not to record any other assets or liabilities at fair value. No events occurred during the fiscal years ended October 31, 2013 or 2012 that required adjustment to the recognized balances of assets or liabilities, which are recorded at fair value on a nonrecurring basis.

The carrying value of cash, restricted cash, accounts receivable, accounts payable and accrued liabilities approximates fair value due to the short maturity of these instruments. The Company obtains fair value measurements from an independent pricing service for corn derivative contracts.  The fair value measurements consider observable data that may include dealer quotes and live trading levels from the Chicago Board of Trade and New York Mercantile Exchange markets. The fair value of the long-term debt is estimated based on anticipated interest rates which management believes would currently be available to the Company for similar issues of debt, taking into account the current credit risk of the Company and other market factors. The Company believes the carrying value of the debt instruments approximate fair value.

Derivatives, Methods of Accounting, Hedging Derivatives [Policy Text Block]

Derivative Instruments

From time to time the Company enters into derivative transactions to hedge its exposures to commodity price fluctuations. The Company is required to record these derivatives in the balance sheets at fair value.

In order for a derivative to qualify as a hedge, specific criteria must be met and appropriate documentation maintained. Gains and losses from derivatives that do not qualify as hedges, or are undesignated, must be recognized immediately in earnings. If the derivative does qualify as a hedge, depending on the nature of the hedge, changes in the fair value of the derivative will be either offset against the change in fair value of the hedged assets, liabilities, or firm commitments through earnings or recognized in other comprehensive income until the hedged item is recognized in earnings. Changes in the fair value of undesignated derivatives are recorded in earnings.

Additionally, the Company is required to evaluate its contracts to determine whether the contracts are derivatives. Certain contracts that literally meet the definition of a derivative may be exempted 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 accounting and reporting requirements, and therefore, are not marked to market in our financial statements.

In order to reduce the risks caused by market fluctuations, the Company occasionally hedges its anticipated corn, natural gas, and denaturant purchases and ethanol sales by entering into options and futures contracts. These contracts are used with the intention to fix the purchase price of anticipated requirements for corn in the Company's ethanol production activities and the related sales price of ethanol. The fair value of these contracts is based on quoted prices in active exchange-traded or over-the-counter market conditions. Although the Company believes its commodity derivative positions are economic hedges, none have been formally designated as a hedge for accounting purposes and derivative positions are recorded on the balance sheet at their fair market value, with changes in fair value recognized in current period earnings or losses. The Company does not enter into financial instruments for trading or speculative purposes.

The Company has adopted authoritative guidance related to “Derivatives and Hedging,” and has included the required enhanced quantitative and qualitative disclosure about objectives and strategies for using derivatives, quantitative disclosures about fair value amounts of gains and losses from derivative instruments, and disclosures about credit-risk-related contingent features in derivative agreements. See further discussion in Note 5.

Income Tax, Policy [Policy Text Block]

Income Taxes

The Company is treated as a partnership for federal and state income tax purposes, and generally does not incur income taxes. Instead its earnings and losses are included in the income tax returns of its members. Therefore, no provision or liability for federal or state income taxes has been included in these financial statements. The Company had no significant uncertain tax positions as of October 31, 2013 or 2012. For years before fiscal 2011, the Company is no longer subject to U.S. Federal or state income tax examinations.

Environmental Costs, Policy [Policy Text Block]

Environmental Liabilities

The Company's operations are subject to environmental laws and regulations adopted by various governmental entities 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 location. 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 liability is probable and the costs can be reasonably estimated. No expense has been recorded for the fiscal years ended October 31, 2013, 2012, or 2011.

Earnings Per Share, Policy [Policy Text Block]

Net Income per Unit

Basic net income per unit is computed by dividing net income by the weighted average number of members' units outstanding during the period. 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, for all periods presented, the calculations of the Company's basic and diluted net income per unit are the same.

Business Combinations Policy [Policy Text Block]

Business Combinations

The Company allocates the total purchase price of a business combination to the assets acquired and the liabilities assumed based on their estimated fair values at the acquisition date, with the excess purchase price recorded as goodwill. The Company used current market data to assist them in determining the fair value of the assets acquired and liabilities assumed, including goodwill, based on recognized business valuation methodology. Subsequent to the acquisition but not to exceed one year from the acquisition date, the Company will record any material adjustments retrospectively to the initial estimate based on new information obtained about facts and circumstances that existed as of the acquisition date. The Company expenses any acquisition-related costs as incurred in connection with business combinations. An income, market or cost valuation method may be utilized to estimate the fair value of the assets acquired or liabilities assumed in a business combination. The income valuation method represents the present value of future cash flows over the life of the asset using (i) discrete financial forecasts, which rely on management's estimates of revenue and operating expenses, (ii) long-term growth rates, and (iii) an appropriate discount rate. The market valuation method uses prices paid for a reasonably similar asset by other purchasers in the market, with adjustments relating to any differences between the assets. The cost valuation method is based on the replacement cost of a comparable asset at prices at the time of the acquisition reduced for depreciation of the asset.

Goodwill and Intangible Assets, Goodwill, Policy [Policy Text Block]

Goodwill

Goodwill represents the cost in excess of the fair value of net assets acquired. The Company conducts impairment assessments annually or when events indicate a triggering event has occurred.

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Commitments and Contingencies

12 Months Ended

Oct. 31, 2013

Commitments and Contingencies [Abstract]

Commitments and Contingencies

COMMITMENTS AND CONTINGENCIES

Corn Storage and Grain Handling Agreement and Purchase Commitments

GFE has a corn storage and grain handling agreement with Farmers Cooperative Elevator (FCE), a member. Under the agreement, the Company agrees to purchase all of the corn needed for the operation of the plant FCE. The price of the corn purchased will be the bid price FCE establishes for the plant plus a set fee of per bushel.

At October 31, 2013, GFE had basis contracts for forward corn purchase commitments with FCE for 350,000 bushels for delivery in November 2013. At October 31, 2013, the Company also had 550,000 bushels of stored corn totaling approximately $2,346,000 with FCE that is included in inventory.

The Company purchased approximately $153,216,000 of corn from the member during fiscal 2013, of which approximately $4,002,000 is included in corn payable at October 31, 2013. The Company purchased approximately $148,289,000 of corn from the member during fiscal 2012, of which approximately $1,996,000 is included in corn payable at October 31, 2012. The Company purchased approximately $123,676,000 of corn from the member during fiscal 2011.

Ethanol Marketing Agreement

GFE currently has an Ethanol Marketing Agreement (“Eco Agreement”) with Eco-Energy, Inc. (“Eco-Energy”). Pursuant to the Eco Agreement, Eco-Energy agrees to purchase the entire ethanol output of GFE's ethanol plant and to arrange for the transportation of ethanol; however, GFE is responsible for securing all of the rail cars necessary for the transport of ethanol by rail. GFE will pay Eco-Energy a certain percentage of the FOB plant price in consideration of Eco-Energy's services. The contract had an initial term of one year, and will continue to remain in effect until terminated by either party at its unqualified option, by providing written notice of not less than 90 days to the other party.

Ethanol marketing fees and commissions totaled approximately $796,000, $743,000, and $1,006,000 for the fiscal years ended October 31, 2013, 2012 and 2011 respectively, and are included net within revenues.

During the fourth quarter of fiscal year 2013, HLBE entered into a new marketing agreement with Eco-Energy, for the sale of ethanol. Under this ethanol agreement, Eco-Energy will purchase, market and resell 100% of the ethanol produced at the Company's ethanol production facility and the Company will pay Eco-Energy a marketing fee based on a percentage of the applicable sale price of the ethanol. The marketing fee was negotiated based on prevailing market-rate conditions for comparable ethanol marketing services.

Ethanol Contracts

At October 31, 2013, GFE had forward contracts to sell approximately $6,283,000 of ethanol for various delivery periods from November 2013 through December 2013 which approximates 36% of its anticipated ethanol sales during that period.

At October 31, 2012, GFE had forward contracts to sell approximately $8,747,000 of ethanol for delivery in November 2012.

Distillers Grain Marketing Agreement

GFE has a Marketing Agreement with RPMG, an unrelated party, for the purpose of marketing and selling all distillers grains produced by the Company. The contract commenced on February 1, 2011 with an initial term of one year, and will continue to remain in effect until terminated by either party at its unqualified option, by providing written notice of not less than 90 days to the other party. Distillers grain commissions totaled approximately $745,000, $650,000 and $460,000 for the fiscal years ended October 31, 2013, 2012 and 2011 respectively, and are included net within revenues.

At October 31, 2013, GFE had forward contracts to sell approximately $3,052,000 of distillers grains for delivery in November 2013 through March 2014 which approximates 27% of its anticipated distillers grain sales during that period.

At October 31, 2012, GFE had forward contracts to sell approximately $1,773,000 of distillers grains for delivery in November 2012 which approximates 65%.

Gavilon Ingredients, LLC serves as the distillers' grains marketer for HLBE pursuant to an off-take agreement that became effective as of November 1, 2013. Under this agreement, Gavilon Ingredients, LLC purchases all of the distillers' grains produced at our Heron Lake ethanol plant in exchange for a service fee.

Corn Oil Marketing Agreement

GFE has a Marketing Agreement with RPMG, an unrelated party, for the purpose of marketing and selling all corn oil produced by the Company. The contract commenced on April 29, 2010 with an initial term of one year, and will continue to remain in effect until terminated by either party at its unqualified option, by providing written notice of not less than 90 days to the other party. Corn oil commissions totaled approximately $74,000, $55,000 and $44,000 for the fiscal years ended October 31, 2013, 2012 and 2011 respectively, and are included net within revenues.

Natural Gas Contracts

At October 31, 2013, GFE had no forward contracts to purchase natural gas.

At October 31, 2012, GFE had forward contracts to purchase $719,000 of natural gas at prices with delivery periods from November 2012 through March 2013.    

HLBE has natural gas agreements with a minimum purchase commitment of approximately 1,600,000 MMBTU per year until October 31, 2014.

Contract for Natural Gas Pipeline to Plant

GFE has an agreement with an unrelated company for the construction of and maintenance of 9.5 miles of natural gas pipeline that will serve the plant. The agreement requires the Company to receive a minimum of 1,400,000 DT of natural gas annually through the term of the agreement. The Company is charged a fee based on the amount of natural gas delivered through the pipeline.

This agreement will continue in effect until December 31, 2015 at which time it will automatically renew for consecutive terms of one year. A twelve months prior written notice is required to be given by either party to terminate this agreement.

At the HLBE plant, we have a facilities agreement with Northern Border Pipeline Company which allows us access to an existing interstate natural gas pipeline located approximately 16 miles north from the plant. Agrinatural Gas, LLC ("Agrinatural Gas"), owned by our subsidiary, HLBE Pipeline Company, LLC, and Rural Energy Solutions, was formed to own and operate the pipeline and transports gas to HLBE pursuant to a transportation agreement. HLBE Pipeline Company, LLC owns 73% of Agrinatural Gas. HLBE also has a base agreement for the sale and purchase of natural gas with Constellation NewEnergy—Gas Division, LLC ("Constellation"). HLBE buys all of its natural gas from Constellation and this agreement runs for a three year period from November 1, 2011 to October 31, 2014.

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Fair Value

12 Months Ended

Oct. 31, 2013

Fair Value [Abstract]

Fair Value

FAIR VALUE

The following table provides information on those derivative assets measured at fair value on a recurring basis at October 31, 2013:

	Carrying Amount in Balance Sheet October 31, 2013			Fair Value October 31, 2013			Fair Value Measurement Using
							Quoted Prices in Active Markets (Level 1)			Significant Other Observable Inputs (Level 2)		Significant unobservable inputs (Level 3)
Financial Liabilities:
Derivative Instruments	$	(75,113	)	$	(75,113	)	$	(75,113	)	$	—	$	—

The following table provides information on those derivative assets measured at fair value on a recurring basis at October 31, 2012:

	Carrying Amount in Balance Sheet October 31, 2012			Fair Value October 31, 2012			Fair Value Measurement Using
							Quoted Prices in Active Markets (Level 1)			Significant Other Observable Inputs (Level 2)		Significant unobservable inputs (Level 3)
Financial Liabilities:
Derivative Instruments	$	(45,563	)	$	(45,563	)	$	(45,563	)	$	—	$	—

We determine the fair value of commodity derivative instruments by obtaining 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 Chicago Board of Trade market and New York Mercantile Exchange.

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Revolving Line of Credit & Long Term Debt

12 Months Ended

Oct. 31, 2013

Debt Disclosure [Abstract]

Debt Disclosure [Text Block]

Granite Falls Energy:

GFE has two credit facilities with a lender. The first is a seasonal revolving operating loan facility in the amount of $5,660,000. The second is a revolving term loan facility in the amount of $18,000,000. However, the amount available for borrowing under this facility reduces by $2,000,000 semi-annually beginning September 1, 2014, with final payment due March 1, 2018.

The interest rates for both facilities are based on the bank's "One Month LIBOR Index Rate," plus 2.8% and 3.05% on the seasonal and revolving term commitments, respectively. The facilities are available through March 31, 2017 and March 31, 2018, respectfully. The outstanding balance on the revolving term loan on October 31, 2013 and October 31, 2012 was $2,513,674 and $4,891,952, respectively. GFE currently has no outstanding balance on the seasonal revolving operating loan facility.

The credit facilities require GFE to comply with certain financial covenants. As of October 31, 2013 and October 31, 2012, GFE was in compliance with these financial covenants and expects to be in compliance throughout fiscal 2014.

The credit facilities are secured by substantially all assets of the Company. There are no savings account balance collateral requirements as part of this credit facility.

At October 31, 2013, GFE also had letters of credit totaling $337,928 with the bank as part of a credit requirement of Northern Natural Gas. These letters of credit were reduced by $49,000 in November 2013.

As part of the acquisition of Project Viking discussed in Note 3, GFE assumed a note payable with Granite Falls Bank with a principal amount of $5,000,000. This note was paid in full on August 19, 2013.

Also, as part of the acquisition of Project Viking discussed in Note 3, GFE issued a note payable to the previous owners of Project Viking with a principal amount of $4,024,500. The note matured on August 30, 2013 and interest accrued on the note at a rate of 4% per annum. This note was paid in full on August 26, 2013.

Heron Lake BioEnergy:

Term Note Payable

On May 17, 2013, HLBE renegotiated its term loan with AgStar in the amount of $17,400,000.  HLBE must make equal monthly payments of principal and interest on the term loan based on a 10-year amortization, provided the entire principal balance and accrued and unpaid interest on the term loan is due and payable in full on the maturity date of September 1, 2016.  In addition, HLBE is required to make additional payments annually on debt for up to 25%of the excess cash flow, as defined by the agreement, up to $2,000,000 per year.  Through September 1, 2014, the loan bears interest at 5.75% as long as HLBE is in compliance with their debt covenants.

On September 1, 2014, the interest term loan will be adjusted to LIBOR plus 3.50% but not less than 5%.  The loan agreements are secured by substantially all business assets and are subject to various financial and non-financial covenants that limit distributions and debt and require minimum debt service coverage, net worth, and working capital requirements.  HLBE was in compliance with the covenants of its master loan agreement with AgStar as of October 31, 2013.

Revolving Term Note

HLBE also obtained a three-year term revolving loan commitment in the amount of $20,500,000, under which AgStar agreed to make periodic advances to HLBE up to this original amount until September 1, 2016. Amounts borrowed by HLBE under the term revolving loan and repaid or prepaid may be re-borrowed at any time prior to maturity date of the term revolving loan, provided that outstanding advances may not exceed the amount of the term revolving loan commitment. Amounts outstanding on the term revolving loan bear interest at a variable rate equal to the greater of a LIBOR rate plus 3.50% or 5.0%, payable monthly. HLBE also pays an unused commitment fee on the unused portion of the term revolving loan commitment at the rate of 0.35% per annum, payable in arrears in quarterly installments during the term of the term revolving loan. Under the terms of the new agreement, the term revolving loan commitment is scheduled to decline by $2,000,000 annually, beginning on October 31, 2013 and each anniversary date thereafter. The maturity date of the term revolving loan is September 1, 2016.

Subordinated Convertible Debt

On May 17, 2013, HLBE’s previous Board of Governors loaned the Company approximately $1,400,000 as part of the convertible secured debt offering. An additional $3,700,000 was raised as part of a convertible debt offering during September 2013. The convertible secured debt is subordinated to the AgStar debt. The notes bear interest at 7.25% and are due in May 2018. On October 1, 2014, or immediately prior to the sale of all or effectively all of HLBE assets, each note is convertible to Class A stock at a rate of $0.30 per Class A unit. HLBE reserves the right to issue Class B units upon conversion if the principal balance of the convertible debt exceeds the authorized Class A units at the conversion rate. At the issuance, each debt holder had the option to convert to Class A units. As a result, holders elected to convert $934,500 in September for 3,115,000 Class A units.

Long-term debt consists of the following:

	October 31, 2013		October 31, 2012
GRANITE FALLS ENERGY:
Capital One Shuttlewagon Railcar Mover (5 year term at 3.875%, due in monthly installments of $10,995)	$	382,918	$	497,636
Revolving Term Loan	2,513,674		4,891,952
HERON LAKE BIOENERGY:
Term note payable to lending institution (including premium of approximately $1.74m)	18,317,800		—
Revolving term note payable to lending institution (including premium of approximately $283k)	6,263,158		—
Assessment payable as part of water treatment agreement, due in semi-annual installments of $189,393 with interest at 6.55%, enforceable by statutory lien, with the final payment due in 2021. The Company made deposits for one years' worth of debt service payments that are held on deposit to be applied with the final payments of the assessment.	2,246,771		—
Assessment payable as part of water treatment agreement, due in semi-annual installments of $25,692 with interest at 0.50%, enforceable by statutory lien, with the final payment due in 2016.	152,698		—
Assessment payable as part of water supply agreement, due in monthly installments of $3,942 with interest at 8.73%, enforceable by statutory lien, with the final payment due in 2019.	205,209		—
Note payable to electrical company with monthly payments of $6,250 with a 1% maintenance fee due each October, due September 2017. The electrical company is a member of the Company.	293,750		—
Note payable to a lending institution for the construction of the pipeline assets initially due in December 2011, converted in February 2012 to a term loan with a three year repayment period. Interest is at 5.29% and the note, along with the line of credit in Note 8, is secured by substantially all assets of Agrinatural.	1,013,132		—
Note payable to noncontrolling interest member of Agrinatural. Interest is at 5.425%, with a maturity date of October 2014.	300,000		—
Equipment payable on corn oil separation equipment from a vendor. The Company pays approximately $40,000 per month conditioned upon revenue generated from the corn oil equipment. The monthly payment includes implicit interest of 5.57% until maturity in May 2015 and the note is secured by the equipment.	640,653		—
Subordinated Convertible Debt with interest of 7.25% paid on a semi-annual basis.	4,143,000		—
Totals	36,472,763		5,389,588
Less amounts due within one year	3,490,808		114,718
Net long-term debt	$	32,981,955	$	5,274,870

Estimated maturities of long-term debt at October 31, 2013 are as follows: 

2014	$	3,490,808
2015	2,846,762
2016	21,602,578
2017	522,563
2018	7,022,813
After 2018	987,239
Total long-term debt	$	36,472,763

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Leases

12 Months Ended

Oct. 31, 2013

Leases [Abstract]

Leases

LEASES

GFE has a lease agreement with a leasing company for 75 hopper cars to assist with the transport of distiller's grains by rail. In November 2010, the original lease was renewed for an additional five-year period. Based on final manufacturing and interest costs, the Company will pay the leasing company $620 per month plus $0.03 per mile traveled in excess of 36,000 miles per year. Rent expense for these leases was $557,000, $552,000 and $553,000 for the fiscal years ended October 31, 2013, 2012 and 2011, respectively.

GFE has lease agreements with three leasing companies for 176 rail car leases for the transportation of the Company's ethanol with various maturity dates through October 2017. The rail car lease payments are due monthly in the aggregate amount of approximately $121,000. Rent expense for these leases was $1,437,000, $1,278,000 and $1,171,000 for the fiscal years ended October 31, 2013, 2012 and 2011, respectively.

HLBE leases equipment, primarily rail cars, under operating leases through 2017. Rent expense for fiscal 2013, 2012, and 2011 was approximately $1,800,000, $2,200,000, and $1,800,000, respectively.

At October 31, 2013, the Company had the following commitments for payments of rentals under operating leases which at inception had a non-cancelable term of more than one year:

November 1, 2013 to October 31, 2014	$	2,602,286
November 1, 2014 to October 31, 2015	1,640,775
November 1, 2015 to October 31, 2016	940,910
November 1, 2016 to October 31, 2017	474,004
November 1, 2017 to October 31, 2018	60,816
Total minimum lease commitments	$	5,718,791

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Members' Equity

12 Months Ended

Oct. 31, 2013

Members' Equity [Abstract]

Members' Equity

MEMBERS' EQUITY

The Company has one class of membership units. The units have no par value and have identical rights, obligations and privileges. Income and losses are allocated to all members based upon their respective percentage of units held. As of October 31, 2013, 2012 and 2011, the Company had 30,606, 30,606 and 30,656 membership units authorized, issued, and outstanding, respectfully.

Subsequent to year end, in December 2013, the Board of Governors declared a cash distribution of $180 per unit or $5,509,080 for unit holders of record as of December 19, 2013. The distribution was paid on December 31, 2013.

In December 2011, the Board of Governors exercised its discretion to redeem 50 membership units totaling $66,420 from an investor due to a unique restriction on transfers situation.

In October 2011, the Board of Governors declared a cash distribution of $300 per unit or $9,196,800 for unit holders of record as of October 27, 2011. The distribution was paid on December 15, 2011.

In November 2010, the Board of Governors declared a cash distribution of $300 per unit or $9,196,800 for unit holders of record as of November 23, 2010. The distribution was paid on December 15, 2010.

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Summary of Significant Accounting Policies Narrative (Details)	3 Months Ended	12 Months Ended
	Oct. 31, 2013	Oct. 31, 2013 gal
Equity Method Investment, Ownership Percentage	60.80%	60.80%
Noncontrolling Interest, Ownership Percentage by Noncontrolling Owners	39.20%	39.20%
Granite Falls Energy [Member]
Plant production capacity		60,000,000
Production (Actual)		70,000,000
Measurement, Rolling Twelve Months	12
Heron Lake Bioenergy [Member]
Plant production capacity		55,000,000
Heron Lake Bioenergy [Member] | Maximum [Member]
Plant production capacity		59,200,000

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Concentrations Narrative (Details)	3 Months Ended	12 Months Ended
	Jan. 31, 2013	Oct. 31, 2013 Ethanol Contracts [Member]	Oct. 31, 2012 Ethanol Contracts [Member]	Oct. 31, 2011 Ethanol Contracts [Member]	Oct. 31, 2013 Distillers Grain & Corn Oil Contracts [Member]	Oct. 31, 2012 Distillers Grain & Corn Oil Contracts [Member]	Oct. 31, 2011 Distillers Grain & Corn Oil Contracts [Member]
Revenue, Major Customer [Line Items]
Entity-Wide Revenue, Major Customer, Percentage	100.00%	64.00%	80.00%	83.00%	19.00%	21.00%	17.00%
Entity-Wide Accounts Receivable, Major Customer, Percentage		65.00%	81.00%		20.00%	18.00%

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Legal Proceedings

12 Months Ended

Oct. 31, 2013

Legal Proceedings [Abstract]

Legal Proceedings

LEGAL PROCEEDINGS

From time to time in the ordinary course of business, the Company may be named as a defendant in legal proceedings related to various issues, including without limitation, workers' compensation claims, tort claims, or contractual disputes.  We are not currently a party to any material pending legal proceedings and we are not currently aware of any such proceedings contemplated by governmental authorities.

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Inventory by Process (Tables)

12 Months Ended

Oct. 31, 2013

Inventory in Process [Abstract]

Schedule of Inventory, Current [Table Text Block]

Inventories consist of the following:

	October 31, 2013		October 31, 2012
Raw materials	$	4,652,465	$	8,977,820
Spare parts	1,636,466		584,011
Work in process	1,643,574		1,150,239
Finished goods	4,437,772		1,557,546
Totals	$	12,370,277	$	12,013,169

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Income Taxes Narrative (Details) (USD $)	12 Months Ended
	Oct. 31, 2013	Oct. 31, 2012
Income Tax Disclosure [Abstract]
Income Tax Reconciliation, Change in Deferred Tax Assets Valuation Allowance	$ 112,673,222	$ 61,133,132
Capitalized start-up costs	625,720	715,109
Income Tax Reconciliation, Income Tax Expense (Benefit), at Federal Statutory Income Tax Rate	(24,977,852)	(25,653,678)
Unrealized Gain (Loss) on Derivatives	75,113	45,563
Capitalized inventory	35,761	10,957
Consolidation, Less than Wholly Owned Subsidiary, Parent Ownership Interest, Changes, Net	(10,396,697)	0
Net Income, Tax Basis of Assets	78,035,267	36,251,083
Net Income, Financial Statement Basis of Liabilities	44,305,219	11,277,807
Debt premium	(2,023,441)	0
Net Income, Tax Basis of Liabilities	$ 42,281,778	$ 11,277,807

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Derivative Instrument Asset & Liabilities (Details) (USD $)	Oct. 31, 2013	Oct. 31, 2012
Derivatives, Fair Value [Line Items]
Derivative Assets, Current	$ 0	$ 0
Derivative Liabilities, Current	(75,113)	(45,563)
Corn Contracts [Member]
Derivatives, Fair Value [Line Items]
Derivative Assets, Current	0	0
Derivative Liabilities, Current	$ (75,113)	$ (45,563)

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Statement of Changes in Members' Equity (USD $)	Total	Parent [Member]	Noncontrolling Interest [Member]
Members' Equity at Oct. 31, 2010	$ 55,862,882	$ 55,862,882	$ 0
Distribution Made to Member or Limited Partner, Cash Distributions Paid	(18,393,600)	(18,393,600)	0
Net Income (Loss) Attributable to Noncontrolling Interest	0
Net Income (Loss) Attributable to Parent	12,291,856	12,291,856	0
Members' Equity at Oct. 31, 2011	49,761,138	49,761,138	0
Net Income (Loss) Attributable to Noncontrolling Interest	0
Stock Repurchased During Period, Value	(66,420)	(66,420)	0
Net Income (Loss) Attributable to Parent	160,607	160,607	0
Members' Equity at Oct. 31, 2012	49,855,325	49,855,325	0
Income (Loss) from Continuing Operations, Including Portion Attributable to Noncontrolling Interest	7,159,741	0	7,159,741
Distribution Made to Member or Limited Partner, Cash Distributions Paid	5,509,080
Noncontrolling Interest, Decrease from Distributions to Noncontrolling Interest Holders	(38,336)	0	(38,336)
Noncontrolling Interest, Increase from Equity Issuance or Sale of Parent Equity Interest	832,500	0	832,500
Net Income (Loss) Attributable to Noncontrolling Interest	526,752	0	526,752
Net Income (Loss) Attributable to Parent	10,032,021	10,032,021	0
Members' Equity at Oct. 31, 2013	$ 68,368,003	$ 59,887,346	$ 8,480,657

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Acquisition (Notes)

12 Months Ended

Oct. 31, 2013

Equity Method Investments and Joint Ventures [Abstract]

Schedule of Business Acquisitions, by Acquisition [Table Text Block]

Cash	$	1,022,764
Restricted cash	510,955
Accounts receivable	3,107,121
Inventory	2,303,157
Prepaid expenses	1,107,025
Property, plant, and equipment	51,625,774
Other assets	924,252
Goodwill	1,372,473
Total assets acquired	$	61,973,521
Accounts payable	$	(936,893	)
Accrued expenses	(399,623		)
Notes payable	(36,452,764		)
Non-controlling interest	(7,159,741		)
Net purchase price	$	17,024,500

BUSINESS COMBINATION

On July 31, 2013, the Company acquired 63.3% of the outstanding membership units of Heron Lake BioEnergy, LLC (“HLBE”) through its purchase of 100% of the membership units of Project Viking, L.L.C. (“Project Viking”), for a total purchase price of $17,024,500. HLBE is a 50 million gallon per year ethanol plant located in Heron Lake, Minnesota. Project Viking was formed by the previous investor to only hold equity interests in HLBE and the debt incurred to obtain those interests and did not have any other assets or liabilities. The previous owner of Project Viking also owned approximately 12.82% of the outstanding membership units of the Company at July 31, 2013.

Immediately following the closing, the Company, through its 100% ownership of Project Viking, owned 24,080,949 Class A units and 15,000,000 Class B units of HLBE, for a total of 39,080,949 units, or 63.3% of the 61,697,104 outstanding units. As a result, under HLBE's member control agreement, Project Viking is entitled to appoint five (5) of the nine (9) governors to HLBE's board of governors.

On July 31, 2013, the Company entered into a Management Services Agreement with HLBE. Under the Management Services Agreement, the Company agreed to supply its own personnel to act as part-time officers and managers of HLBE for the positions of Chief Executive Officer, Chief Financial Officer, and Commodity Risk Manager. The initial term of the Management Services Agreement is three years. The Company will be paid $35,000 per month by HLBE for the first year of the Management Services Agreement. During years two and three of the agreement, HLBE agreed to pay the Company 50% of the total salary, bonuses, and other expenses and costs incurred by the Company for the three management positions. At the expiration of the initial term, the Management Services Agreement will automatically renew for successive one-year terms unless and until the Company or HLBE gives the other party 90-days written notice of termination prior to expiration of the initial term or the start of a renewal term.

The acquisition date fair value of the consideration transferred consisted of the following:

Cash	$	8,000,000
Note payable	4,024,500
Assumption of note payable to Granite Falls Bank	5,000,000
Total Consideration	$	17,024,500

The assets and liabilities of Project Viking were recorded at their respective estimated fair values as of the date of the acquisition using generally accepted accounting principles for business combinations. The Company used a combination of the market and cost approaches that included unobservable level 3 inputs, to estimate the fair values of the assets acquired and liabilities assumed. The fair value of the long-term debt acquired was determined based on the present value of future contractual cash flows discounted at an interest rate that reflects the current borrowing rates available to the Company for loans with similar terms. The fair market value of the debt assumed was approximately $36.5 million and resulted in a debt premium balance of approximately $2.3 million being recorded as of the acquisition date. The debt premium is amortized as a reduction of interest expense over the term of the debt using the effective interest method. The value of the 36.66% noncontrolling interest was determined by using the fair value method by using the most recent arms-length transaction of HLBE's units that did not include a control premium. The goodwill is attributable to the synergies expected to arise after the acquisition in the purchasing of inputs and the sale of outputs.  Goodwill is not expected to be deductible for tax purposes.  The fair value of the assets acquired includes account receivables of approximately $3,107,000, all of which are expected to be collectible.

Subsequent to the initial purchase price allocation and within the one year measurement period, new information was obtained about facts and circumstances that existed as of the acquisition date. As such, the purchase price allocation of the HLBE acquisition was retroactively adjusted to include the effect of this measurement period adjustment.  An adjustment of approximately $273k was recorded to adjust the fair value of a noncontrolling interest in HLBE, which was adjusted through goodwill during the fourth quarter ended October 31, 2013. The retroactively adjusted purchase price allocation is as follows:

Cash	$	1,022,764
Restricted cash	510,955
Accounts receivable	3,107,121
Inventory	2,303,157
Prepaid expenses	1,107,025
Property, plant, and equipment	51,625,774
Other assets	924,252
Goodwill	1,372,473
Total assets acquired	$	61,973,521
Accounts payable	$	(936,893	)
Accrued expenses	(399,623		)
Notes payable	(36,452,764		)
Non-controlling interest	(7,159,741		)
Net purchase price	$	17,024,500

The acquisition occurred on the last day of the Company's fiscal third quarter, therefore the Company consolidated three months of HLBE's revenues and expenses in the consolidated statements of operations. HLBE contributed revenues of $38,560,522 and earnings of $1,305,044 to the Company for the three month period from August 1, 2013 to October 31, 2013. The net income attributable to non-controlling interests for the year ended October 31, 2013 totaled approximately $527,000.

The following represents the unaudited pro forma consolidated statement of operations as if the transaction occurred at the beginning of the following periods:

	For the years ended
	October 31, 2013		October 31, 2012			October 31, 2011
	Unaudited		Unaudited			Unaudited
Revenues	$	349,304,556	$	343,821,978		$	320,641,864
Net income, including portion attributable to non-controlling interest of $712,289, ($20,702,684), and $361,351, respectively	$	4,864,820	$	(31,794,779	)	$	13,612,987
Earnings per share (30,606, 30,614, and 30,656 weighted average units outstanding - basic and diluted, respectively)	$	116.16	$	(617.00	)	$	412.75

The pro forma financial information is presented for informational purposes only and is not indicative of the results of operations that would have been achieved if the acquisition had taken place at the beginning of each of the periods presented. These amounts have been calculated after adjusting the results of HLBE to reflect the additional amortization of the debt premium that would have occurred assuming the fair value adjustment to long-term debt had been applied at the beginning of each period presented.

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Derivative Instruments (Tables)

12 Months Ended

Oct. 31, 2013

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Schedule of Derivative Instruments in Statement of Financial Position, Fair Value [Table Text Block]

The following tables provide details regarding the Company's derivative instruments at October 31, 2013, none of which were designated as hedging instruments:

	Balance Sheet location	Assets		Liabilities
Corn contracts	Commodity derivative instruments	$	—	$	(75,113	)
Totals		$	—	$	(75,113	)

The following tables provide details regarding the Company's derivative instruments at October 31, 2012, none of which were designated as hedging instruments:

	Balance Sheet location	Assets		Liabilities
Corn contracts	Commodity derivative instruments	$	—	$	(45,563	)
Totals		$	—	$	(45,563	)

Schedule of Derivative Instruments, Gain (Loss) in Statement of Financial Performance [Table Text Block]

The following tables provide details regarding the gains and (losses) from Company's derivative instruments in statements of operations, none of which are designated as hedging instruments:

	Statement of	Fiscal Years Ended October 31,
	Operations location	2013		2012			2011
Ethanol contracts	Revenue	$	—	$	—		$	(4,626	)
Corn contracts	Cost of Goods Sold	155,563		(1,651,799		)	1,280,413
Natural gas contracts	Cost of Goods Sold	—		—			(4,545		)
Total gain (loss)		$	155,563	$	(1,651,799	)	$	1,271,242

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Inventory Narrative (Details) (USD $)	12 Months Ended
	Oct. 31, 2012
Lower of Cost of Market Adjustment	$ 77,000

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Concentrations

12 Months Ended

Oct. 31, 2013

Concentrations [Abstract]

Concentrations

On July 31, 2013, the Company acquired 63.3% of the outstanding membership units of Heron Lake BioEnergy, LLC (“HLBE”) through its purchase of 100% of the membership units of Project Viking, L.L.C. (“Project Viking”), for a total purchase price of $17,024,500. HLBE is a 50 million gallon per year ethanol plant located in Heron Lake, Minnesota. Project Viking was formed by the previous investor to only hold equity interests in HLBE and the debt incurred to obtain those interests and did not have any other assets or liabilities. The previous owner of Project Viking also owned approximately 12.82% of the outstanding membership units of the Company at July 31, 2013.

Immediately following the closing, the Company, through its 100% ownership of Project Viking, owned 24,080,949 Class A units and 15,000,000 Class B units of HLBE, for a total of 39,080,949 units, or 63.3% of the 61,697,104 outstanding units. As a result, under HLBE's member control agreement, Project Viking is entitled to appoint five (5) of the nine (9) governors to HLBE's board of governors.

On July 31, 2013, the Company entered into a Management Services Agreement with HLBE. Under the Management Services Agreement, the Company agreed to supply its own personnel to act as part-time officers and managers of HLBE for the positions of Chief Executive Officer, Chief Financial Officer, and Commodity Risk Manager. The initial term of the Management Services Agreement is three years. The Company will be paid $35,000 per month by HLBE for the first year of the Management Services Agreement. During years two and three of the agreement, HLBE agreed to pay the Company 50% of the total salary, bonuses, and other expenses and costs incurred by the Company for the three management positions. At the expiration of the initial term, the Management Services Agreement will automatically renew for successive one-year terms unless and until the Company or HLBE gives the other party 90-days written notice of termination prior to expiration of the initial term or the start of a renewal term.

The acquisition date fair value of the consideration transferred consisted of the following:

Cash	$	8,000,000
Note payable	4,024,500
Assumption of note payable to Granite Falls Bank	5,000,000
Total Consideration	$	17,024,500

The assets and liabilities of Project Viking were recorded at their respective estimated fair values as of the date of the acquisition using generally accepted accounting principles for business combinations. The Company used a combination of the market and cost approaches that included unobservable level 3 inputs, to estimate the fair values of the assets acquired and liabilities assumed. The fair value of the long-term debt acquired was determined based on the present value of future contractual cash flows discounted at an interest rate that reflects the current borrowing rates available to the Company for loans with similar terms. The fair market value of the debt assumed was approximately $36.5 million and resulted in a debt premium balance of approximately $2.3 million being recorded as of the acquisition date. The debt premium is amortized as a reduction of interest expense over the term of the debt using the effective interest method. The value of the 36.66% noncontrolling interest was determined by using the fair value method by using the most recent arms-length transaction of HLBE's units that did not include a control premium. The goodwill is attributable to the synergies expected to arise after the acquisition in the purchasing of inputs and the sale of outputs.  Goodwill is not expected to be deductible for tax purposes.  The fair value of the assets acquired includes account receivables of approximately $3,107,000, all of which are expected to be collectible.

Subsequent to the initial purchase price allocation and within the one year measurement period, new information was obtained about facts and circumstances that existed as of the acquisition date. As such, the purchase price allocation of the HLBE acquisition was retroactively adjusted to include the effect of this measurement period adjustment.  An adjustment of approximately $273k was recorded to adjust the fair value of a noncontrolling interest in HLBE, which was adjusted through goodwill during the fourth quarter ended October 31, 2013. The retroactively adjusted purchase price allocation is as follows:

Cash	$	1,022,764
Restricted cash	510,955
Accounts receivable	3,107,121
Inventory	2,303,157
Prepaid expenses	1,107,025
Property, plant, and equipment	51,625,774
Other assets	924,252
Goodwill	1,372,473
Total assets acquired	$	61,973,521
Accounts payable	$	(936,893	)
Accrued expenses	(399,623		)
Notes payable	(36,452,764		)
Non-controlling interest	(7,159,741		)
Net purchase price	$	17,024,500

The acquisition occurred on the last day of the Company's fiscal third quarter, therefore the Company consolidated three months of HLBE's revenues and expenses in the consolidated statements of operations. HLBE contributed revenues of $38,560,522 and earnings of $1,305,044 to the Company for the three month period from August 1, 2013 to October 31, 2013. The net income attributable to non-controlling interests for the year ended October 31, 2013 totaled approximately $527,000.

The following represents the unaudited pro forma consolidated statement of operations as if the transaction occurred at the beginning of the following periods:

	For the years ended
	October 31, 2013		October 31, 2012			October 31, 2011
	Unaudited		Unaudited			Unaudited
Revenues	$	349,304,556	$	343,821,978		$	320,641,864
Net income, including portion attributable to non-controlling interest of $712,289, ($20,702,684), and $361,351, respectively	$	4,864,820	$	(31,794,779	)	$	13,612,987
Earnings per share (30,606, 30,614, and 30,656 weighted average units outstanding - basic and diluted, respectively)	$	116.16	$	(617.00	)	$	412.75

The pro forma financial information is presented for informational purposes only and is not indicative of the results of operations that would have been achieved if the acquisition had taken place at the beginning of each of the periods presented. These amounts have been calculated after adjusting the results of HLBE to reflect the additional amortization of the debt premium that would have occurred assuming the fair value adjustment to long-term debt had been applied at the beginning of each period presented.