LAKE AREA CORN PROCESSORS LLC - Annual Report: 2011 (Form 10-K)
UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 10-K
x | Annual report pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934. |
For the fiscal year ended December 31, 2011 | |
o | Transition report pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934. |
Commission file number 000-50254 | |
LAKE AREA CORN PROCESSORS, LLC | |||
(Exact name of registrant as specified in its charter) | |||
South Dakota | 46-0460790 | ||
(State or other jurisdiction of incorporation or organization) | (I.R.S. Employer Identification No.) | ||
46269 SD Highway 34 P.O. Box 100 Wentworth, South Dakota | 57075 | ||
(Address of principal executive offices) | (Zip Code) | ||
(605) 483-2676 | |||
(Registrant's telephone number, including area code) | |||
Securities registered pursuant to Section 12(b) of the Act: None | |||
Securities registered pursuant to Section 12(g) of the Act: Membership Units | |||
Indicate by check mark if the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act.
o Yes x No
Indicate by check mark if the registrant is not required to file reports pursuant to Section 13 or Section 15(d) of the Act.
o Yes x No
Indicate by check mark whether the registrant: (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. x Yes o No
Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Website, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files).
x Yes o No
Indicate by check mark if disclosure of delinquent filers pursuant to Item 405 of Regulation S-K (§229.405 of this chapter) is not contained herein, and will not be contained, to the best of registrant's knowledge, in definitive proxy or information statements incorporated by reference in Part III of this Form 10-K or any amendment to this Form 10-K. o
Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, or a smaller reporting company. See the definitions of "large accelerated filer," "accelerated filer" and "smaller reporting company" in Rule 12b-2 of the Exchange Act.
Large accelerated filer o | Accelerated filer o | |
Non-accelerated filer x | Smaller Reporting Company o | |
(Do not check if a smaller reporting company) | ||
Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Act). o Yes x No
As of June 30, 2011, the last day of the registrant's most recently completed second fiscal quarter, the aggregate market value of the registrant's membership units held by non-affiliates of the registrant was $14,218,375 computed by reference to the most recent public offering price on Form S-4.
As of March 23, 2012, there were 29,620,000 membership units of the registrant 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 information 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 (December 31, 2011). This information statement is referred to in this report as the 2012 Information Statement.
INDEX
Page No. | |
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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 terms 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 upon 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:
Ÿ | Availability and costs of raw materials, particularly corn and natural gas; |
Ÿ | Changes in the price and market for ethanol, distillers grains and corn oil; |
Ÿ | Our ability to maintain liquidity and maintain our risk management positions; |
Ÿ | Decreases in the price of gasoline or decreased gasoline demand; |
Ÿ | Changes in the availability and cost of credit; |
Ÿ | Changes and advances in ethanol production technology; |
Ÿ | The effectiveness of our risk management strategy to offset increases in the price of our raw materials and decreases in the prices of our products; |
Ÿ | Overcapacity within the ethanol industry causing supply to exceed demand; |
Ÿ | Our ability to market and our reliance on third parties to market our products; |
Ÿ | The decrease or elimination of governmental incentives which support the ethanol industry; |
Ÿ | Changes in the weather or general economic conditions impacting the availability and price of corn; |
Ÿ | Our ability to generate free cash flow to invest in our business and service our debt; |
Ÿ | Changes in plant production capacity or technical difficulties in operating the plant; |
Ÿ | Changes in our business strategy, capital improvements or development plans; |
Ÿ | Our ability to retain key employees and maintain labor relations; |
Ÿ | Our liability resulting from potential litigation; |
Ÿ | Competition from alternative fuels and alternative fuel additives; and |
Ÿ | Other factors described elsewhere in this report. |
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 undertake no duty to update these forward-looking statements, even though our situation may change in the future. Furthermore, we cannot guarantee future results, events, levels of activity, performance, or achievements. We caution you not to put undue reliance on any forward-looking statements, which speak only as of the date of this report. You should read this report and the documents that we reference in this report and have filed as exhibits completely and with the understanding that our actual future results may be materially different from what we currently expect. We qualify all of our forward-looking statements by these cautionary statements.
PART I
ITEM 1. BUSINESS.
Overview
Lake Area Corn Processors, LLC is a South Dakota limited liability company that owns and manages an ethanol plant that has a nameplate production capacity of 40 million gallons of ethanol per year through its wholly-owned subsidiary Dakota Ethanol, L.L.C. The ethanol plant is located near Wentworth, South Dakota. Lake Area Corn Processors, LLC is referred to in this report as "LACP," the "Company," "we," or "us." Dakota Ethanol, L.L.C. is referred to in this report as "Dakota Ethanol" or the "ethanol plant."
Since September 4, 2001, we have been engaged in the production of ethanol and distillers grains. Fuel grade ethanol is our primary product accounting for the majority of our revenue. We also sell distillers grains and corn oil, the principal co-products of the ethanol production process.
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General Development of Business
LACP was formed as a South Dakota cooperative on May 25, 1999. On August 20, 2002, our members approved a plan to reorganize into a South Dakota limited liability company. The reorganization became effective on August 31, 2002, and the assets and liabilities of the cooperative were transferred to the newly formed limited liability company. Following the reorganization, our legal name was changed to Lake Area Corn Processors, LLC.
Our ownership of Dakota Ethanol represents substantially our only asset and our only source of revenue. Since we operate Dakota Ethanol as a wholly-owned subsidiary, all revenues generated by Dakota Ethanol are passed to LACP. We make distributions of the income received from Dakota Ethanol to our unit holders in proportion to the number of units held by each member compared to the units held by our members generally.
On June 6, 2011, we executed amended loan agreements with our primary lender, First National Bank of Omaha. Following the amendments, the face amount of our short-term revolving loan increased from $5 million to $10 million and the maturity date of our short-term revolving loan was extended to May 1, 2012. In addition, we agreed that the principal amount of our long-term revolving loan would decrease by $500,000 each year until maturity. Therefore, on May 1, 2012, the maximum amount of the long-term revolving loan will decrease to $4.5 million and on May 1, 2013 will decrease to $4 million. The maturity date of our long-term revolving loan was extended to May 1, 2014. Our credit facilities are described in greater detail below in the section entitled "Item 7 - Management's Discussion and Analysis of Financial Condition and Results of Operations - Indebtedness."
Our board of managers declared and paid four separate distributions during our 2011 fiscal year, in May, July, November and December 2011. Each distribution was in the amount of $0.10 per membership unit, for a total of $0.40 per membership unit for the year. The total distribution that we paid during our 2011 fiscal year was $11,848,000.
Also, we received a settlement payment of $1 million related to a prior legal matter during our third quarter of 2011. This settlement is subject to a confidential settlement agreement.
Financial Information
Please refer to "Item 7 - Management's Discussion and Analysis of Financial Condition and Results of Operations" for information regarding our results of operations and "Item 8 - Financial Statements and Supplementary Data" for our audited consolidated financial statements.
Principal Products
The principal products produced at the ethanol plant are fuel grade ethanol, distillers grains and corn oil. The table below shows the approximate percentage of our total revenue which is attributed to each of our primary products for each of our last three fiscal years.
Product | Fiscal Year 2011 | Fiscal Year 2010 | Fiscal Year 2009 | ||||||
Ethanol | 82 | % | 84 | % | 83 | % | |||
Distillers Grains | 15 | % | 14 | % | 16 | % | |||
Corn Oil | 3 | % | 2 | % | 1 | % | |||
Ethanol
Ethanol is ethyl alcohol, a fuel component made primarily from corn and various other grains. Ethanol is primarily used for blending with unleaded gasoline and other fuel products. The vast majority of the ethanol that is produced in the United States uses corn as the feedstock in the ethanol production process. Corn produces large quantities of carbohydrates, which convert into glucose more easily than most other kinds of biomass.
An ethanol plant is essentially a fermentation plant. Ground corn and water are mixed with enzymes and yeast to produce a substance called "beer," which contains approximately 15% alcohol, 11% solids and 74% water. The "beer" is boiled to separate the water, resulting in ethyl alcohol, which is then dehydrated to increase the alcohol content. This product is then mixed with a certified denaturant, such as gasoline, to make the product unfit for human consumption which allows it to be sold commercially.
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Ethanol 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. Used as a fuel oxygenate, ethanol provides a means to control carbon monoxide emissions in large metropolitan areas where oxygenated fuels are required during certain times of the year.
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 and beef industry. We primarily produce distillers grains in two forms, modified/wet distillers grains and dried distillers grains. Modified/wet distillers grains have a higher moisture content than dried distillers grains. Our modified/wet distillers grains are used primarily in our local market because they have a shorter shelf life and are more expensive to transport than dried distillers grains. Approximately 75% of the distillers grains we sell are in the modified/wet form and approximately 25% are in the dried form.
Corn Oil
During our 2009 fiscal year, we commenced operating our corn oil extraction equipment which allows us to separate some of the corn oil contained in our distillers grains. The corn oil that we produce is not food grade corn oil and therefore cannot be used for human consumption without further refining. However, corn oil can be used as the feedstock to produce biodiesel and has other industrial and feed uses.
Incentive Revenue
We receive incentive revenue from the State of South Dakota associated with our production of ethanol. In each of our last three fiscal years, this incentive revenue accounted for less than 1% of our total revenue.
Principal Product Markets
Ethanol
The primary market for our ethanol is the domestic fuel blending market. However, during 2011, the United States ethanol industry experienced increased ethanol exports to Brazil, the European Union and Canada. Due to our location, we do not anticipate a significant amount of the ethanol we produce will be exported. Ethanol is generally blended with gasoline before it is sold to the end consumer. Therefore, the primary purchasers of ethanol are fuel blending companies who mix the ethanol we produce with gasoline. As discussed below in the section entitled "Distribution of Principal Products," we have a third party marketer that sells all of our ethanol. Our ethanol marketer makes all decisions regarding where our ethanol is sold.
Below is a chart showing the price for ethanol futures at the Chicago Mercantile Exchange during our last three fiscal years.
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Please see "Item 7 - Management's Discussion and Analysis of Financial Condition and Results of Operations" for management's discussion of ethanol prices.
Distillers Grains
Distillers grains are primarily used as an animal feed substitute. Distillers grains are typically fed to animals instead of other traditional animal feeds such as corn and soybean meal. We market a portion of our distillers grains through a third-party marketer and we market a portion of our distillers grains directly into our local market without the assistance of a third party marketer. We believe that nearly all of our distillers grains are sold to consumers in the United States. However, distillers grains exports have increased recently as distillers grains have become a more accepted animal feed substitute. During 2010, China significantly increased its distillers grains imports as China continues to expand its animal feeding industry and as Chinese consumers increase their meat consumption. However, late in 2010, China instituted an investigation of the United States distillers grains industry based on claims that the United States was dumping distillers grains in China. While management believes that China's dumping claims are without merit, this investigation and subsequent actions by the Chinese government have decreased distillers grains exports to China. Management believes China's dumping investigation is at odds with market conditions in China where animal feeding operations continue to demand additional distillers grains from the United States. Other key importers of distillers grains are Mexico, Canada and Vietnam. Despite the recent increases in distillers grains exports, we anticipate that the vast majority of our distillers grains will continue to be sold in the domestic market due to our plant's location.
Below is a chart showing the market price for distillers grains compared to corn and soybean meal prices during our last three fiscal years.
Distribution of Principal Products
Ethanol Distribution
On November 30, 2005, we entered into an Ethanol Fuel Marketing Agreement with Renewable Products Marketing Group ("RPMG") of Shakopee, Minnesota, for the purposes of marketing and distributing our ethanol. On April 1, 2007, we became an owner of RPMG by making a capital contribution to RPMG. Our capital contribution was $605,000, of which $105,000 was paid at the time we became an owner of RPMG and the balance was paid over time with a portion of our ethanol sales revenue. We have fully paid our capital contribution to RPMG. Becoming an owner of RPMG allows us to share any profits made by RPMG and reduces the fees that we pay RPMG to market our ethanol. We pay RPMG a fee to market our ethanol based on RPMG's actual cost to market our ethanol. On March 26, 2010, we entered into a new ethanol marketing agreement with RPMG
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on essentially the same terms as our previous agreement. The new ethanol marketing agreement changes the manner in which our marketing fee is calculated which did not have a material effect on our marketing fees.
Distillers Grains Distribution
Other than the distillers grains that we market locally without a third party marketer, our distillers grains are marketed by RPMG, the same entity that markets our ethanol and corn oil. On July 15, 2008 we entered into a distillers grains marketing agreement with RPMG. The initial term of our distillers grains marketing agreement with RPMG was two years. Our distillers grains marketing agreement with RPMG automatically renews for additional one-year terms unless notice of termination is given as provided by the distillers grains marketing agreement. We pay RPMG a commission based on each ton of distillers grains sold by RPMG.
We market a portion of our distillers grains to our local market without the use of an external marketer. Currently, we market approximately 75% of our distillers grains internally. Shipments of these products are made to local markets by truck. This has allowed us to sell less distillers grains in the form of dried distillers grains which has decreased our natural gas usage and increased our revenues from the sale of distillers grains.
Corn Oil Distribution
We market all of our corn oil through RPMG, which is the same entity that markets our ethanol and distillers grains. On August 11, 2009, we executed a corn oil marketing agreement with RPMG. The initial term of the agreement was for one year. The agreement automatically renews for additional one year terms unless either party gives 180 days notice that the agreement will not be renewed. We agreed to pay RPMG a commission based on each pound of our corn oil that is sold by RPMG.
New Products and Services
We did not introduce any new products or services during our 2011 fiscal year.
Patents, Trademarks, Licenses, Franchises and Concessions
We do not currently hold any patents, trademarks, franchises or concessions. We were granted a license by Broin and Associates, Inc., the company that designed and built the ethanol plant, to use certain ethanol production technology necessary to operate our ethanol plant. The cost of the license granted by Broin was included in the amount we paid to Broin to design and build our ethanol plant.
Sources and Availability of Raw Materials
Corn Feedstock Supply
The major raw material required for our ethanol plant to produce ethanol, distillers grains and corn oil is corn. The plant operates in excess of its nameplate capacity of 40 million gallons of ethanol per year, producing approximately 47 million gallons of ethanol annually from approximately 17.1 million bushels of corn. The area surrounding the ethanol plant currently provides an ample supply of corn to meet and exceed our raw material requirements for the production capacity of the plant.
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Below is a chart showing the price for corn futures at the Chicago Mercantile Exchange during our last three fiscal years.
Corn prices have been volatile in recent years due to changes in supply and demand as well as yield and production fluctuations that have had a significant impact on corn prices. Corn prices have been higher due to lower corn carryover in 2010 and 2011 along with strong corn demand. Corn prices have typically fluctuated based on supply and demand factors as well as weather conditions that affect corn yields, both nationally and within our local corn market.
Corn is supplied to us primarily from our members who are local agricultural producers and from purchases of corn on the open market. Certain of our members have corn delivery contracts that require them to supply us with corn as a condition of being a member of the company. On August 1, 2007, our board of managers approved a resolution making it voluntary for these members to deliver corn to us under their respective corn delivery agreements. We anticipate that many of our members will continue to supply us with corn on a voluntary basis. We anticipate purchasing corn from third parties should our members fail to supply us with enough corn to operate the ethanol plant at capacity.
In February 2009, we entered into an agreement with John Stewart & Associates ("JS&A") to provide us with consulting services related to our risk management strategy. We agreed to pay JS&A a fee of $2,500 per month to assist us in making risk management decisions regarding our commodity purchases. The initial term of the agreement was one year and thereafter it renews on a month-to-month basis.
Natural Gas
Natural gas is an important input to our manufacturing process. We have a contract with Centerpoint Energy Services for the supply of our natural gas. Under our agreement, the price for our natural gas is based on market rates. We contract with NorthWestern Energy for the transportation of our natural gas. The transportation agreement was renewed in 2011 for an additional ten-year term until 2021. Since operations commenced in 2001, there have been no interruptions in the supply of natural gas from NorthWestern Energy, and all of our natural gas requirements have been met. Recently, we have experienced decreases in natural gas prices which have followed energy and commodity prices generally. We anticipate that natural gas prices will continue to remain low with the typical premium natural gas prices during the winter months. However, should we experience supply interruptions during our 2012 fiscal year, such as from hurricane activity in the Gulf Coast region of the United States, we may experience higher natural gas prices. Some believe that due to recent increases in natural gas production in the United States, the United States may start exporting natural gas in the future. If this were to occur, it may result in higher natural gas prices in the United States due to increased demand. The United States has been able to increase natural gas production due to a process called hydraulic fracturing frequently referred to as "fracking." However, the natural gas industry is experiencing challenges to this natural gas production process. If fracking is banned or limited due to these challenges, it could lead to less natural gas production which may negatively impact natural gas prices.
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Below is a chart showing the spot market price of natural gas during our last three fiscal years.
Electricity
Electricity is necessary for lighting and powering much of the machinery and equipment used in the production process. We contract with Sioux Valley Energy, Inc. to provide all of the electric power and energy requirements for the ethanol plant. We have had no interruptions or shortages in the supply of electricity to the plant since operations commenced in 2001.
Water
Water is a necessary part of the ethanol production process. It is used in the fermentation process and to produce steam for the cooking, evaporation, and distillation processes. We contract with Big Sioux Community Water System, Inc. to meet our water requirements. Our agreement with Big Sioux is for a five-year term commencing in August 2009 and is renewable for additional five year terms. Since our operations commenced in September 2001, we have had no interruption in the supply of water and all of our requirements have been met.
Seasonal Factors in Business
We anticipate some seasonality of demand for ethanol during the summer months that coincides with increases in gasoline demand. Since ethanol is typically blended with gasoline, when gasoline demand changes, ethanol demand typically changes correspondingly. Distillers grains demand decreases during the summer months when domestic animal feeding operations typically reduce the size of their herds. In addition, we experience some seasonality in the price we pay for natural gas with premium pricing during the winter months. This increase in natural gas prices coincides with increased natural gas demand for heating needs in the winter months.
Dependence on One or a Few Major Customers
As discussed above, we have entered into marketing agreements with RPMG to market our ethanol, distillers grains and corn oil. Therefore, we rely on RPMG to market almost all of our products, except for the distillers grains that we market locally. Our financial success will be highly dependent on RPMG's ability to market our products at competitive prices. Any loss of RPMG as our marketing agent or any lack of performance under these agreements or inability to secure competitive prices could have a significant negative impact on our revenues. While we believe we can secure new marketers if RPMG were to fail, we may not be able to secure such new marketers at rates which are competitive with RPMG's.
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Our Competition
We are in direct competition with numerous ethanol producers in the sale of our products and with respect to raw material purchases related to those products. Many of the ethanol producers with which we compete have greater resources than we do. While management believes we are a lower cost producer of ethanol, larger ethanol producers may be able to take advantage of economies of scale due to their larger size and increased bargaining power with both ethanol, distillers grains and corn oil customers and raw material suppliers. As of March 8, 2012, the Renewable Fuels Association estimates that there are 210 ethanol production facilities in the United States with capacity to produce approximately 14.8 billion gallons of ethanol per year. According to RFA estimates, approximately 6% of the ethanol production capacity in the United States was not operating as of March 8, 2012. The largest ethanol producers include Archer Daniels Midland, Green Plains Renewable Energy, POET, and Valero Renewable Fuels, each of which are capable of producing significantly more ethanol than we produce.
The following table identifies the largest ethanol producers in the United States along with their production capacities.
U.S. FUEL ETHANOL PRODUCTION CAPACITY
BY TOP PRODUCERS
Producers of Approximately 700
million gallons per year (MMgy) or more
Company | Current Capacity (MMgy) | Under Construction/Expansions (MMgy) | ||||
Archer Daniels Midland | 1,750 | — | ||||
POET Biorefining | 1,629 | — | ||||
Valero Renewable Fuels | 1,130 | — | ||||
Green Plains Renewable Energy | 730 | — | ||||
Updated: March 8, 2012
The products that we produce are commodities. Since our products are commodities, there are typically no significant differences between the products we produce and the products of our competitors that would allow us to distinguish our products in the market. As a result, competition in the ethanol industry is primarily based on price and consistent fuel quality. Management believes we are a lower cost producer of ethanol and that we have an experienced management team operating our ethanol plant. However, larger ethanol producers may be able to realize economies of scale in their operations than we are able to realize due to their increased bargaining power. This could put us at a competitive disadvantage to other ethanol producers. These larger ethanol producers may be able to enter into more favorable arrangements to purchase raw materials and also may be able to receive a higher price for the ethanol and co-products they produce due to the size of their operations.
In 2008, Valero Renewable Fuels, which is a subsidiary of a major gasoline refining company, purchased several ethanol plants. Currently, Valero Renewable Fuels owns 10 ethanol plants with capacity to produce approximately 1.1 billion gallons of ethanol annually. This makes Valero Renewable Fuels one of the largest ethanol producers in the United States. Further, since the parent company of Valero Renewable Fuels is a gasoline blender, Valero Renewable Fuels has an established customer for the ethanol it produces which may allow Valero Renewable Fuels to be more competitive in the ethanol industry. At times when ethanol demand may be lower, it is unlikely that Valero Renewable Fuels will have difficulty selling the ethanol it produces. While Valero is currently the largest oil company which has purchased a significant amount of ethanol production capacity, other large oil companies may follow the lead of Valero in the future. Should other large oil companies become involved in the ethanol industry, it may be increasingly difficult for us to compete and to find customers for our ethanol.
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. Currently, cellulosic ethanol production technology is not sufficiently advanced to produce cellulosic ethanol on a commercial scale. However, due to government incentives designed to encourage innovation in the production of cellulosic ethanol, we anticipate that commercially viable cellulosic ethanol technology will be developed in the future. Several companies and researchers have commenced pilot projects to study the feasibility of commercially producing cellulosic ethanol. 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
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or result in competitive disadvantages for our ethanol production process.
A number of automotive, industrial and power generation manufacturers are developing alternative clean power systems using fuel cells, plug-in hybrids, electric cars or clean burning gaseous fuels. Electric car technology has recently grown in popularity, especially in urban areas. While there are currently a limited number of vehicle recharging stations, making electric cars not feasible for all consumers, there has been increased focus on developing these recharging stations to make electric car technology more widely available in the future. Additional competition from these other sources of alternative energy, particularly in the automobile market, could reduce the demand for ethanol, which would negatively impact our profitability.
Distillers Grains Competition
Our ethanol plant competes with other ethanol producers in the production and sales of distillers grains. Distillers grains are primarily used as an animal feed supplement which replaces corn and soybean meal. As a result, we believe that distillers grains prices are positively impacted by increases in corn and soybean prices. In addition, in 2010 and 2011 the United States ethanol industry has increased exports of distillers grains which management believes has positively impacted demand and prices for distillers grains in the United States. In the event these distillers grains exports decrease, such as due to tariffs being imposed by the Chinese government following its anti-dumping investigation, it could lead to an oversupply of distillers grains. This could result in increased competition among ethanol producers for sales of distillers grains which could negatively impact distillers grains prices in the United States.
Research and Development
We do not conduct any research and development activities associated with the development of new technologies for use in producing ethanol, distillers grains and corn oil.
Governmental Regulation
Federal Ethanol Supports
The ethanol industry is dependent on several economic incentives to produce ethanol, including federal tax incentives and ethanol use mandates. The most significant federal ethanol support is the Federal Renewable Fuels Standard (the "RFS"). The RFS requires that in each year, a certain amount of renewable fuels must be used in the United States. The RFS is a national program that does not require that any renewable fuels be used in any particular area or state, allowing refiners to use renewable fuel blends in those areas where it is most cost-effective. The RFS 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 cellulosic ethanol and biomass based biodiesel but not ethanol that is made from corn. 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 for 2011 was approximately 14 billion gallons, of which corn based ethanol could be used to satisfy approximately 12.6 billion gallons. The RFS for 2012 is approximately 15.2 billion gallons, of which corn based ethanol can be used to satisfy approximately 13.2 billion gallons. Current ethanol production capacity exceeds the 2012 RFS requirement which can be satisfied by corn based ethanol. Certain states have requested waivers from the RFS program which would limit the amount of the mandated use of biofuels. Management does not believe that any waivers will be granted. However, if a change in administration were to occur, a waiver of the RFS might be a possibility. In addition, recently there has been legislation proposed which would reduce or eliminate the RFS. While management does not believe that these pieces of legislation will be passed into law, if they were passed we anticipate that it would significantly decrease demand for and market prices of ethanol in the United States.
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 130 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 billion gallons per year. This is commonly referred to as the "blending 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 and ethanol exports. Many in the ethanol industry believe that we have reached the blending wall or will reach it soon. However, the RFS requires that 36 billion gallons of renewable fuels must be used each year in the United States by 2022, which equates to approximately 27%
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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.
Recently, the United States Environmental Protection Agency allowed 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. The fact that E15 is not approved for use in all vehicles may negatively impact the availability of E15. In addition, there are still regulatory hurdles that need to be addressed before management believes E15 will be readily available in the market. The EPA is requiring a label for E15 that management believes may discourage consumers from using E15. As a result of these obstacles to the implementation of E15, management believes that the limited approval of E15 may not have an immediate impact on ethanol demand in the United States.
In addition to the RFS, the ethanol industry was previously benefited by the Volumetric Ethanol Excise Tax Credit ("VEETC"). VEETC provided a volumetric ethanol excise tax credit of 4.5 cents per gallon of gasoline that contains at least 10% ethanol (total credit of 45 cents per gallon of ethanol blended which is 4.5 divided by the 10% blend). However, VEETC expired on December 31, 2011 and management does not believe it will be renewed. Management believes that the elimination of VEETC will not have a significant effect on prices and demand for ethanol as most of the benefit from VEETC was received by gasoline blenders. Management believes that due to the RFS use requirements, demand for ethanol will continue to mirror the RFS requirement, despite the elimination of VEETC. However, if the RFS is reduced or eliminated, the decrease in demand for ethanol related to the elimination of VEETC will be more substantial.
The USDA announced that it will provide financial assistance to help implement more "blender pumps" in the United States in order to increase demand for ethanol and to help offset the cost of introducing mid-level ethanol blends into the United States retail gasoline market. A blender pump is a gasoline pump that can dispense a variety of ethanol/gasoline blends. Blender pumps typically can dispense E10, E20, E30, E40, E50 and E85. These blender pump accomplish these different ethanol/gasoline blends by internally mixing ethanol and gasoline which are held in separate tanks at the retail gas stations. Many in the ethanol industry believe that increased use of blender pumps will increase demand for ethanol by allowing gasoline retailers to provide various mid-level ethanol blends in a cost effective manner and allowing consumers with flex-fuel vehicles to purchase more ethanol through these mid-level blends. However, blender pumps cost approximately $25,000 each, so it may take time before they become widely available in the retail gasoline market.
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 plant. It is possible that more stringent federal or state environmental rules or regulations could be adopted, which could increase our operating costs and expenses. It also is possible that federal or state environmental rules or regulations could be adopted that could have an adverse effect on the use of ethanol. Plant operations are governed by the Occupational Safety and Health Administration ("OSHA"). OSHA regulations may change such that the costs of operating the plant may increase. Any of these regulatory factors may result in higher costs or other adverse conditions effecting our operations, cash flows and financial performance.
In late 2009, California passed a Low Carbon Fuels Standard ("LCFS"). The California LCFS requires that renewable fuels used in California must accomplish certain reductions in greenhouse gases which is measured using a lifecycle analysis, similar to the RFS. On December 29, 2011, a federal court in California ruled that the California LCFS was unconstitutional. This ruling has halted implementation of the California LCFS. However, the California Air Resources Board ("CARB") has appealed this court ruling which could result in the reinstatement of the California LCFS in the future.
Costs and Effects of 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. We have obtained all of the necessary permits to operate the plant. Although we have been successful in obtaining all of the permits currently required, any retroactive change in environmental regulations, either at the federal or state level, could require us to obtain additional permits or spend considerable resources on complying with such regulations. In addition, we may be required to purchase and install equipment for controlling and improving emissions. During our 2011 fiscal year, our costs of environmental compliance were approximately $157,000. We anticipate that our environmental compliance costs will be approximately $125,000 during our 2012 fiscal year because we will have less extensive environmental testing required for environmental permit renewals we will apply for during our 2012 fiscal year.
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We are subject to environmental oversight by the EPA. There is always a risk that the EPA may enforce certain rules and regulations differently than South Dakota's environmental administrators. South Dakota or EPA rules are subject to change, and any such changes could result in greater regulatory burdens on plant operations. We could also be subject to environmental or nuisance claims from adjacent property owners or residents in the area arising from possible foul smells or other air or water discharges from the plant. Such claims may result in an adverse result in court if we are deemed to engage in a nuisance that substantially impairs the fair use and enjoyment of property.
Employees
As of March 23, 2012, we had a total of 38 full-time employees. We do not expect to hire a significant number of employees in the next 12 months.
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 2011, 2010 and 2009 were produced in the United States and all of our long-lived assets are domiciled in the United States. We have engaged a third-party professional marketer which decides where the majority of our products are marketed and we have no control over the marketing decisions made by our third-party professional marketer. Therefore, some of our products may be sold outside of the United States based on decisions made by our marketer.
ITEM 1A. RISK FACTORS.
You should carefully read and consider the risks and uncertainties below and the other information contained in this report. The risks and uncertainties described below are not the only ones we may face. The following risks, together with additional risks and uncertainties not currently known to us or that we currently deem immaterial could impair our financial condition and results of operation.
Risks Relating to Our Business
The spread between ethanol and corn prices can vary significantly and we do not expect the spread to remain at the high levels previously experienced by the ethanol industry. Our only source of revenue comes from sales of our ethanol, distillers grains and corn oil. The primary raw materials we use to produce our ethanol, distillers grains and corn oil are corn and natural gas. In order to operate the ethanol plant profitably, we must maintain a positive spread between the revenue we receive from sales of our products and our corn and natural gas costs. This spread between the market price of our products and our raw material costs has been volatile in the past, and management anticipates that this spread will likely continue to be volatile in the future. Management expects continued tight operating margins during our 2012 fiscal year. If we were to experience a period of time where this spread is negative, and the negative margins continue for an extended period of time, it may prevent us from profitably operating the ethanol plant. If we were to experience negative operating margins, it could decrease the value of our units.
If the RFS is eliminated or reduced, it could negatively impact the price of and demand for ethanol which could negatively impact our profitability. The ethanol industry is benefited by the ethanol use requirement in the Federal Renewable Fuels Standard ("RFS"). The RFS requires that 15.2 billion gallons of renewable fuels must be used in the United States in 2012, including 13.2 billion gallons of corn based ethanol. Recently, there have been various pieces of legislation introduced which would decrease or eliminate the RFS. While these pieces of legislation have not been enacted into law and many believe they would not pass both houses of Congress, the composition of Congress may change in the future and the RFS could be eliminated. If the RFS were to be eliminated or reduced, it could negatively impact demand for ethanol and may lead to significant decreases in the market price of ethanol which could negatively impact our ability to profitably operate the ethanol plant.
Our revenue will be greatly affected by the price at which we can sell our ethanol, distillers grains and corn oil. Our ability to generate revenue is dependent on our ability to sell the ethanol, distillers grains and corn oil that we produce. Ethanol, distillers grains and corn oil prices can be volatile as a result of a number of factors. These factors include overall supply and demand, the market price of corn, the market price of gasoline, level of government support, general economic conditions and the availability and price of competing products. Ethanol, distillers grains and corn oil prices tend to fluctuate based on changes in energy prices and other commodity prices, such as corn and soybean meal. Should we experience decreasing ethanol, distillers grain and corn oil prices, particularly if corn and natural gas prices remain high, we may not be able to profitably operate the ethanol plant. If this continues for a significant period of time, the value of our units may be negatively affected.
Our financial performance is significantly dependent on corn and natural gas prices. Our results of operations and financial condition are significantly affected by the cost and supply of corn and natural gas. Generally, we cannot pass on increases
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in input prices to our customers. 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.
Corn, as with most other crops, is affected by weather, disease and other environmental conditions. The price of corn is also influenced by general economic, market and government factors. These factors include weather conditions, farmer planting decisions, domestic and foreign government farm programs and policies, global demand, supply and quality. Changes in the price of corn can significantly affect our business. Generally, higher corn prices will produce lower profit margins and, therefore, represent unfavorable market conditions. If we endure high corn prices for a sustained period of time without corresponding increases in the selling price of ethanol and distillers grains, such pricing may reduce our ability to operate our ethanol plant profitably. If our region becomes saturated by ethanol plants, corn used for ethanol could consume a significant portion of the total corn production in our region, which would likely increase local corn prices. We may not be able to offset an increase in the price of corn by increasing the price of our products.
The prices for and availability of natural gas are subject to volatile market conditions, including supply shortages and infrastructure incapacities. Significant disruptions in the supply of natural gas could impair our ability to operate the ethanol plant. During the end of 2005 and early 2006, natural gas supply disruptions as a result of hurricanes in the Gulf Coast led to historically high natural gas prices. At any time, similar supply disruptions may increase the price we pay for natural gas.
Increases in the price we pay for corn and natural gas, without corresponding increases in the price we receive for our ethanol, distillers grains and corn oil, may make our ethanol plant operate unprofitably which could reduce or eliminate the value of our units.
Our business is not diversified. Our success depends on our ability to profitably operate our ethanol plant. We do not have any other lines of business or other sources of revenue if we are unable to operate our ethanol plant and manufacture ethanol, distillers grains and corn oil. If economic or political factors adversely affect the market for ethanol, distillers grains and corn oil, we may not be able to continue our operations. Our business would also be significantly harmed if our ethanol plant could not operate at full capacity for any extended period of time. This could reduce or eliminate the value of our units.
Our inability to secure credit facilities we may require in the future may negatively impact our liquidity. Due to current conditions in the credit markets, it has been difficult for businesses to secure financing. While we do not currently require more financing than we have, in the future we may need additional financing. Our $10 million line of credit will need to be renewed in May 2012. We plan to renew this line of credit but we may be unsuccessful in doing so. If we require financing in the future and we are unable to secure such financing, or we are unable to secure the financing we require on reasonable terms, it may have a negative impact on our liquidity. This could negatively impact the value of our units.
Advances in ethanol production technology could require us to incur costs to update our plant or could otherwise hinder our ability to compete or operate profitably. Advances and changes in the technology of ethanol production are expected to occur. Such advances and changes may make the ethanol production technology installed in our plant less desirable or obsolete. These advances could also allow our competitors to produce ethanol at a lower cost than us. If we are unable to adopt or incorporate technological advances, our ethanol production methods and processes could be less efficient than our competitors, which could cause our plant to become uncompetitive or completely obsolete. If our competitors develop, obtain or license technology that is superior to ours or that makes our technology obsolete, we may be required to incur significant costs to enhance or acquire new technology so that our ethanol production remains competitive. Alternatively, we may be required to seek third-party licenses, which could also result in significant expenditures. These third-party licenses may not be available or, once obtained, may not continue to be available on commercially reasonable terms. These costs could negatively impact our financial performance by increasing our operating costs and reducing our net income.
Our product marketer may fail to market our products at competitive prices which may cause us to operate unprofitably. RPMG is the sole marketer of all of our ethanol, corn oil and most of our distillers grains, and we rely heavily on its marketing efforts to successfully sell our products. Because RPMG sells ethanol, corn oil and distillers grains for a number of other producers, we have limited control over its sales efforts. Our financial performance is dependent upon the financial health of RPMG as most of our revenues are attributable to RPMG's sales. If RPMG breaches our marketing agreements or it cannot market all of the ethanol, corn oil and distillers grains we produce, we may not have any readily available means to sell our ethanol, corn oil and distillers grains and our financial performance could be negatively affected. While we market a portion of our distillers grains internally to local consumers, we do not anticipate that we would have the ability to sell all of the distillers grains, corn oil and ethanol we produce ourselves. If our agreements with RPMG terminate, we may seek other arrangements to sell our ethanol, corn oil and distillers grains, including selling our own product, but we may not be able to achieve results comparable to those achieved by RPMG which could harm our financial performance.
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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 corn and natural gas price volatility. We may choose not to engage in hedging transactions in the future and our operations and financial conditions may be adversely affected during periods in which corn and/or natural gas prices increase. Significant losses on our hedging activities may cause us to operate unprofitably and could decrease the value of our units.
We may incur casualty losses that are not covered by insurance which could negatively impact the value of our units. We have purchased insurance which we believe adequately covers our losses from foreseeable risks. However, there are risks that we may encounter for which there is no insurance or for which insurance is not available on terms that are acceptable to us. If we experience a loss which materially impairs our ability to operate the ethanol plant which is not covered by insurance, the value of our units could be reduced or eliminated.
Our operations may be negatively impacted by natural disasters, severe weather conditions, and other unforeseen plant shutdowns which can negatively impact our operations. Our operations may be negatively impacted by events outside of our control such as natural disasters, severe weather, strikes, train derailments and other unforeseen events which may negatively impact our operations. If we experience any of these unforeseen circumstances which negatively impact our operations, it may affect our cash flow and negatively impact the value of our business.
We depend on our management and key employees, and the loss of these relationships could negatively impact our ability to operate profitably. We are highly dependent on our management team to operate our ethanol plant. While we seek to compensate our management and key employees in a manner that will encourage them to continue their employment with us, they may choose to seek other employment. Any loss of these managers or key employees may prevent us from operating the ethanol plant profitably and could decrease the value of our units.
We may violate the terms of our credit agreement and financial covenants which could result in our lender demanding immediate repayment of our loans. Current management projections indicate that we will be in compliance with our loan covenants for at least the next 12 months. However, unforeseen circumstances may develop which could result in us violating our loan covenants. If we violate the terms of our credit agreement, our primary lender could deem us in default of our loans and require us to immediately repay any outstanding balance of our loans. If we do not have the funds available to repay the loans or we cannot find another source of financing, we may fail which could decrease the value of our units.
Risks Related to Ethanol Industry
Demand for ethanol may not continue to grow unless ethanol can be blended into gasoline in higher percentage blends for standard vehicles. Currently, ethanol is primarily blended with gasoline for use in standard (non-flex fuel) vehicles to create a blend which is 10% ethanol and 90% gasoline. Estimates indicate that approximately 130 billion gallons of gasoline are sold in the United States each year. Assuming that all gasoline in the United States is blended at a rate of 10% ethanol and 90% gasoline, the maximum demand for ethanol is 13 billion gallons. This is commonly referred to as the "blending wall," which represents a theoretical limit where more ethanol cannot be blended into the national gasoline pool. Many in the ethanol industry believe that the ethanol industry has reached the blending wall. Management believes that in order to expand demand for ethanol, higher percentage blends of ethanol must be utilized in standard vehicles. Such higher percentage blends of ethanol are a contentious issue. Automobile manufacturers and environmental groups have fought against higher percentage ethanol blends. Recently, the EPA approved the use of E15 for standard vehicles produced in the model year 2001 and later. However, the fact that E15 has not been approved for use in all vehicles and the labeling requirements associated with E15 may lead to gasoline retailers refusing to carry E15. Without an increase in the allowable percentage blends of ethanol that can be used in all vehicles, demand for ethanol may not continue to increase which could decrease the selling price of ethanol and could result in our inability to operate the ethanol plant profitably. This could reduce the value of our units.
The Federal Volumetric Ethanol Excise Tax Credit ("VEETC") expired on December 31, 2011, which could negatively impact our profitability. The ethanol industry was historically benefited by VEETC which was a federal excise tax credit of 45 cents per gallon of ethanol which is blended with gasoline. VEETC expired on December 31, 2011 and management does not anticipate that it will be reinstated. While management believes that much of the benefit from VEETC went to fuel blenders, it may have benefited the market price of ethanol. If the market price of ethanol falls as a result of the expiration of VEETC, it could negatively impact our ability to profitably operate the ethanol plant which could decrease the value of our units.
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If exports to Europe are decreased due to the recent European anti-dumping investigation, it may negatively impact ethanol prices in the United States. The European Union recently commenced an anti-dumping investigation related to ethanol produced in the United States and exported to Europe. The purpose of the investigation is to determine whether the European Union will impose a tariff on ethanol which is produced in the United States and exported to Europe. Currently, the United States ethanol industry exports a significant amount of ethanol to Europe. If exports of ethanol to Europe decrease as a result of this anti-dumping investigation, it could negatively impact the market price of ethanol in the United States. Any decrease in ethanol prices or demand may negatively impact our ability to profitably operate the ethanol plant.
The price of distillers grains may decline as a result of China's anti-dumping investigation regarding distillers grains originating in the United Sates. At the end of 2010, China commenced an anti-dumping investigation with respect to distillers grains produced in the United States and exported to China. Management believes this anti-dumping investigation reduced distillers grains exports to China in 2011. However, due to increased corn prices, distillers grains demand increased in the United States as well as in Canada and Mexico. China represents a significant market for distillers grains and the loss of distillers grains sales to China could negatively impact prices in the United States, especially during times when distillers grains demand is low in the United States. While management believes that the China anti-dumping claims are without merit and are motivated by other trade disputes between the United States and China, if China imposes a significant tariff it may negatively impact the price we receive for our distillers grains. Management anticipates that the Chinese anti-dumping investigation will be completed during 2012 and does not expect a significant tariff will be imposed. However, the Chinese anti-dumping investigation could result in lower distillers grains prices which could negatively impact our financial performance.
The ethanol industry is changing rapidly which can result in unexpected developments that could negatively impact our operations and the value of our units. The ethanol industry has grown significantly in the last twelve years. According to the Renewable Fuels Association, the ethanol industry has grown from approximately 1.5 billion gallons of production per year in 1999 to nearly 14 billion gallons in 2011. This rapid growth has resulted in significant shifts in supply and demand of ethanol over a very short period of time. As a result, past performance by the ethanol plant or the ethanol industry generally might not be indicative of future performance. We may experience a rapid shift in the economic conditions in the ethanol industry which may make it difficult to operate the ethanol plant profitably. If changes occur in the ethanol industry that make it difficult for us to operate the ethanol plant profitably, it could result in a reduction in the value of our units.
Technology advances in the commercialization of cellulosic ethanol may decrease demand for corn based ethanol which may negatively affect our profitability. The current trend in ethanol production research is to develop an efficient method of producing ethanol from cellulose-based biomass, such as agricultural waste, forest residue, municipal solid waste, and energy crops. This trend is driven by the fact that cellulose-based biomass is generally cheaper than corn, and producing ethanol from cellulose-based biomass would create opportunities to produce ethanol in areas which are unable to grow corn. The Energy Independence and Security Act of 2007 and the 2008 Farm Bill offer strong incentives to develop commercial scale cellulosic ethanol. The RFS requires that 16 billion gallons per year of advanced bio-fuels be consumed in the United States by 2022. Additionally, state and federal grants have been awarded to several companies who are seeking to develop commercial-scale cellulosic ethanol plants. We expect this will encourage innovation that may lead to commercially viable cellulosic ethanol plants in the near future. If an efficient method of producing ethanol from cellulose-based biomass is developed, we may not be able to compete effectively. If we are unable to produce ethanol as cost-effectively as cellulose-based producers, our ability to generate revenue and our financial condition will be negatively impacted.
Overcapacity within the ethanol industry could cause an oversupply of ethanol and a decline in ethanol prices. Excess ethanol production capacity could have an adverse impact on our results of operations, cash flows and general financial condition. If demand for ethanol does not grow at the same pace as increases in supply, we would expect the price of ethanol to decline. If excess capacity in the ethanol industry occurs, the market price of ethanol may decline to a level that is inadequate to generate sufficient cash flow to cover our costs which could reduce the value of our units.
We operate in an intensely competitive industry and compete with larger, better financed companies which could impact our ability to operate profitably. There is significant competition among ethanol producers. There are numerous producer-owned and privately-owned ethanol plants operating throughout the Midwest and elsewhere in the United States. We also face competition from outside of the United States. The passage of the Energy Policy Act of 2005 included a renewable fuels mandate called the Renewable Fuels Standard ("RFS"). The Energy Independence and Security Act of 2007 increased the RFS to 36 billion gallons by 2022. Further, some states have passed renewable fuel mandates. These increases in ethanol demand have encouraged companies to enter the ethanol industry. The largest ethanol producers include POET, Archer Daniels Midland, Green Plains Renewable Energy, and Valero Renewable Fuels, all of which are each capable of producing significantly more ethanol than we produce. We may not be able to compete effectively with these larger ethanol producers. Further, many believe that there will be consolidation occurring in the ethanol industry in the future which could lead to a few companies which control a significant portion of the ethanol production market. These larger ethanol producers may be able to affect the ethanol market in ways that
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are not beneficial to us which could affect our financial performance.
Competition from the advancement of alternative fuels may lessen the demand for ethanol. Alternative fuels, gasoline oxygenates and ethanol production methods are continually under development. A number of automotive, industrial and power generation manufacturers are developing alternative clean power systems using fuel cells, plug-in hybrids, electric cars or clean burning gaseous fuels. Like ethanol, these emerging technologies offer an option to address worldwide energy costs, the long-term availability of petroleum reserves and environmental concerns. If these alternative technologies continue to expand and gain broad acceptance and become readily available to consumers for motor vehicle use, we may not be able to compete effectively. This additional competition could reduce the demand for ethanol, resulting in lower ethanol prices that might adversely affect our results of operations and financial condition.
Consumer beliefs may affect the demand for ethanol. We believe that certain consumers perceive the use of ethanol to have a negative impact on gasoline prices at the pump. Some consumers 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 fuel energy, such as oil and natural gas, than the energy in the ethanol that is produced. These consumer beliefs could potentially be widespread. If consumers choose not to buy ethanol, it will affect the demand for the ethanol we produce which could lower the selling price of ethanol and negatively affect our profitability and financial condition.
Risks Related to Regulation and Governmental Action
Changes in environmental regulations or violations of these regulations could be expensive and reduce our profitability. We are subject to extensive air, water and other environmental laws and regulations. Some of these laws require our plant to operate under a number of environmental permits. These laws, regulations and permits often require expensive pollution control equipment or operational changes to limit actual or potential impacts to the environment. A violation of these laws and regulations or permit conditions can result in substantial fines, damages, criminal sanctions, permit revocations and/or plant shutdowns. In the future, we may be subject to legal actions brought by environmental advocacy groups and other parties for actual or alleged violations of environmental laws or our permits. Additionally, any changes in environmental laws and regulations, both at the federal and state level, could require us to spend considerable resources in order to comply with future environmental regulations. The expense of compliance could be significant enough to reduce our profitability and negatively affect our financial condition.
The California Low Carbon Fuel Standard may decrease demand for corn based ethanol which could negatively impact our profitability. California passed a Low Carbon Fuels Standard ("LCFS"). The California LCFS requires that renewable fuels used in California must accomplish certain reductions in greenhouse gases which are measured using a lifecycle analysis. Management believes that these regulations could preclude corn based ethanol produced in the Midwest from being used in California. California represents a significant ethanol demand market. If we are unable to supply ethanol to California, it could significantly reduce demand for the ethanol we produce. While implementation of the California LCFS has recently been delayed by a court ruling that the law is unconstitutional, this ruling is being appealed by the State of California. Any decrease in ethanol demand as a result of the California LCFS regulations could negatively impact ethanol prices which could reduce our revenues and negatively impact our ability to profitably operate the ethanol plant.
Carbon dioxide regulations may require us to obtain additional permits and install additional environmental mitigation equipment, which could adversely affect our financial performance. Carbon dioxide and other greenhouse gases are regulated as air pollutants under the Clean Air Act. While we currently have all permits necessary under the Clean Air Act to operate the plant, these regulations may change in the future which could require us to apply for additional permits or install carbon dioxide mitigation equipment or take other as yet unknown steps to comply with these potential regulations. Compliance with any future regulation of carbon dioxide, if it occurs, could be costly and may prevent us from operating the ethanol plant profitably which could decrease the value of our units.
ITEM 2. PROPERTIES.
We own Dakota Ethanol as a wholly-owned subsidiary. The ethanol plant is located on Dakota Ethanol's 210-acre rural site near Wentworth, South Dakota. All of our operations occur at our plant in Wentworth, South Dakota.
All of Dakota Ethanol's tangible and intangible property, real and personal, serves as the collateral for debt financing with First National Bank of Omaha described below under "Item 7 - Management's Discussion and Analysis of Financial Condition and Results of Operations - Indebtedness." Further, the additional 135 acres of land we purchased in 2008 is collateral for our debt obligation related to this purchase. We also granted a security interest in our corn oil extraction equipment in exchange for certain equipment financing we received to purchase and install this equipment.
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ITEM 3. LEGAL PROCEEDINGS.
From time to time in the ordinary course of business, Dakota Ethanol or Lake Area Corn Processors may be named as a defendant in legal proceedings related to various issues, including, worker's compensation claims, tort claims, or contractual disputes. We are not currently involved in any material legal proceedings, directly or indirectly, and we are not aware of any claims pending or threatened against us or any of the managers that could result in the commencement of material legal proceedings.
ITEM 4. MINE SAFETY DISCLOSURES
None.
PART II.
ITEM 5. MARKET FOR REGISTRANT'S COMMON EQUITY, RELATED MEMBER MATTERS AND ISSUER PURCHASES OF EQUITY SECURITIES.
Recent Sales of Unregistered Equity Securities
None.
Market Information
There is no public trading market for our units. Our units may only be transferred in accordance with our Capital Units Transfer System, which provides for transfers by gift to family members, upon death, and through a qualified matching service, subject to approval by our board of managers. Our qualified matching service is operated through Variable Investment Advisors, Inc., a registered broker-dealer based in Sioux Falls, South Dakota. Variable Investment Advisor's Alternative Trading System may be accessed at www.agstocktrade.com. The matching service consists of an electronic bulletin board that provides information to prospective sellers and buyers of our units. We do not receive any compensation relating to the matching service. We have no role in effecting the transactions beyond approval, as required under our operating agreement and the issuance of new certificates. So long as we remain a publicly reporting company, information about us will be publicly available through the SEC's filing system.
Unit Holders
As of March 23, 2012, the company had 29,620,000 membership units issued and outstanding and a total of approximately 1,051 unit holders. There is no other class of membership units issued or outstanding.
Bid and Asked Prices
The following table contains information concerning completed unit transactions that occurred during the last two fiscal years. Our bulletin board trading system does not track bid and asked prices and therefore we only have information concerning completed unit transactions.
Quarter | Low Price | High Price | Average Price | Number of Units Traded | |||||||||||
First Quarter 2010 | $ | 1.15 | $ | 1.35 | $ | 1.21 | 32,000 | ||||||||
Second Quarter 2010 | 1.11 | 1.15 | 1.14 | 51,500 | |||||||||||
Third Quarter 2010 | 0.99 | 1.10 | 1.02 | 136,950 | |||||||||||
Fourth Quarter 2010 | 1.00 | 1.02 | 1.01 | 70,000 | |||||||||||
First Quarter 2011 | 0.93 | 1.10 | 1.05 | 145,000 | |||||||||||
Second Quarter 2011 | 0.95 | 1.03 | 0.99 | 77,500 | |||||||||||
Third Quarter 2011 | 1.00 | 1.01 | 1.00 | 110,000 | |||||||||||
Fourth Quarter 2011 | 1.00 | 1.50 | 1.06 | 75,000 | |||||||||||
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Distributions
Under the terms of our Third Amended and Restated Operating Agreement, we are required to make distributions to our members and may not retain more than $200,000 of net cash from operations, unless: (1) a 75% supermajority of our board of managers decides otherwise; (2) it would violate or cause a default under the terms of any debt financing or other credit facilities; or (3) it is otherwise prohibited by law. Our ability to make distributions to our members is dependent upon the distributions made to us by Dakota Ethanol. All net income generated from plant operations is distributed by Dakota Ethanol to us since Dakota Ethanol is our wholly-owned subsidiary. We distribute the net income received from Dakota Ethanol to our unit holders in proportion to the number of units held by each unit holder. A unit holder's distribution percentage is determined by dividing the number of units owned by such unit holder by the total number of units outstanding. We anticipate continuing to monitor our financial performance and projected financial performance and we expect to make distributions at such times and in such amounts as will allow us to continue to profitably operate the ethanol plant, maintain compliance with our loan covenants and maintain our liquidity.
2011 Distributions
Our board of managers declared four distributions during our 2011 fiscal year. Each distribution was for $0.10 per membership unit for a total of $0.40 per membership unit during our 2011 fiscal year. Our distributions were declared and paid in May, July, November and December 2011. The total amount of the distributions we paid was $11,848,000.
2010 Distributions
On November 9, 2010, we declared a distribution of $0.10 per unit to our members of record as of October 1, 2010. This distribution was paid in November 2010. The total amount of the distributions we paid was $2,962,000.
Performance Graph
The following graph shows a comparison of cumulative total member return since January 1, 2007, calculated on a dividend reinvested basis, for the Company, the NASDAQ Composite Index (the "NASDAQ Market Index") and an index of other companies that have the same SIC code as the Company (the "SIC Code Index"). The graph assumes $100 was invested in each of our units, the NASDAQ Market Index, and the SIC Code Index on January 1, 2007. Data points on the graph are annual. Note that historic unit price performance is not necessarily indicative of future unit price performance. The data for this performance graph was compiled for us by Zacks Investment Research, Inc.
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Pursuant to the rules and regulations of the Securities and Exchange Commission, the performance graph and the information set forth therein shall not be deemed to be filed for purposes of Section 18 of the Securities Exchange Act of 1934, and shall not be deemed to be incorporated by reference in any filing under the Securities Act of 1933, as amended, or the Exchange Act, except as shall be expressly set forth by specific reference in such a filing.
ITEM 6. SELECTED FINANCIAL DATA
The following table sets forth selected consolidated financial data, which is derived from our audited financial statements for the periods indicated. The selected consolidated balance sheet financial data as of December 31, 2009, 2008 and 2007 and the selected consolidated income statement data and other financial data for the years ended December 31, 2008 and 2007 have been derived from our audited consolidated financial statements that are not included in this Form 10-K. The selected consolidated balance sheet financial data as of December 31, 2011 and 2010 and the selected consolidated income statement data and other financial data for each of the years in the three year period ended December 31, 2011 have been derived from the audited Consolidated Financial Statements included elsewhere in this Form 10-K. You should read the following table in conjunction with (i) the consolidated financial statements and accompanying notes included elsewhere in this Form 10-K; (ii) "Item 7 - Management's Discussion and Analysis of Financial Condition and Results of Operations" and (iii) "Item 1A - Risk Factors" found elsewhere in this Form 10-K. Among other things, those items include more detailed information regarding the basis of presentation for the following consolidated financial data.
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Statement of Operations Data: | 2011 | 2010 | 2009 | 2008 | 2007 | |||||||||||||||
Revenues | $ | 146,964,854 | $ | 96,395,789 | $ | 90,340,642 | $ | 111,778,588 | $ | 103,739,699 | ||||||||||
Cost of Revenues | 126,626,536 | 86,289,732 | 81,659,486 | 125,413,056 | 80,977,667 | |||||||||||||||
Gross Profit (Loss) | 20,338,318 | 10,106,057 | 8,681,156 | (13,634,468 | ) | 22,762,032 | ||||||||||||||
Operating Expense | 3,246,368 | 2,922,059 | 2,957,809 | 3,534,274 | 3,721,813 | |||||||||||||||
Income (Loss) From Operations | 17,091,950 | 7,183,998 | 5,723,347 | (17,168,742 | ) | 19,040,219 | ||||||||||||||
Other Income (Expense) | 353,596 | (139,436 | ) | (848,578 | ) | 555,293 | (1,035,014 | ) | ||||||||||||
Net Income (Loss) | $ | 17,445,546 | $ | 7,044,562 | $ | 4,874,769 | $ | (16,613,449 | ) | $ | 18,005,205 | |||||||||
Capital Units Outstanding | 29,620,000 | 29,620,000 | 29,620,000 | 29,620,000 | 29,620,000 | |||||||||||||||
Net Income (Loss) Per Capital Unit | $ | 0.59 | $ | 0.24 | $ | 0.16 | $ | (0.56 | ) | $ | 0.61 | |||||||||
Cash Distributions per Capital Unit | $ | 0.40 | $ | 0.10 | $ | — | $ | 0.05 | $ | 0.60 | ||||||||||
Balance Sheet Data: | 2011 | 2010 | 2009 | 2008 | 2007 | |||||||||||||||
Working Capital | $ | 14,191,708 | $ | 6,031,369 | $ | 2,372,783 | $ | (3,068,598 | ) | $ | 16,054,455 | |||||||||
Net Property, Plant & Equipment | 26,473,686 | 29,760,568 | 32,445,979 | 34,531,667 | 35,345,093 | |||||||||||||||
Total Assets | 67,392,852 | 62,178,421 | 58,625,220 | 58,206,448 | 73,554,744 | |||||||||||||||
Long-Term Obligations | 489,432 | 1,181,410 | 3,923,596 | 5,664,276 | 5,077,137 | |||||||||||||||
Member's Equity | 53,694,694 | 48,097,148 | 43,733,907 | 38,859,138 | 56,953,587 | |||||||||||||||
Book Value Per Capital Unit | $ | 1.81 | $ | 1.62 | $ | 1.48 | $ | 1.31 | $ | 1.92 | ||||||||||
ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS
Except for the historical information, the following discussion contains forward-looking statements that are subject to risks and uncertainties. We caution you not to put undue reliance on any forward-looking statements, which speak only as of the date of this report. Our actual results or actions may differ materially from these forward-looking statements for many reasons, including the risks described in "Item 1A - Risk Factors" and elsewhere in this annual report. Our discussion and analysis of our financial condition and results of operations should be read in conjunction with the financial statements and related notes and with the understanding that our actual future results may be materially different from what we currently expect.
Results of Operations
Comparison of Fiscal Years Ended December 31, 2011 and 2010
The following table shows the results of our operations and the percentage of revenues, cost of revenues, operating expenses and other items to total revenues in our consolidated statements of operations for the fiscal years ended December 31, 2011 and 2010:
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2011 | 2010 | |||||||||||||
Income Statement Data | Amount | % | Amount | % | ||||||||||
Revenue | $ | 146,964,854 | 100.0 | $ | 96,395,789 | 100.0 | ||||||||
Cost of Revenues | 126,626,536 | 86.2 | 86,289,732 | 89.5 | ||||||||||
Gross Profit | 20,338,318 | 13.8 | 10,106,057 | 10.5 | ||||||||||
Operating Expense | 3,246,368 | 2.2 | 2,922,059 | 3.0 | ||||||||||
Income from Operations | 17,091,950 | 11.6 | 7,183,998 | 7.5 | ||||||||||
Other Income (Expense) | 353,596 | 0.2 | (139,436 | ) | (0.1 | ) | ||||||||
Net Income | $ | 17,445,546 | 11.9 | $ | 7,044,562 | 7.3 | ||||||||
Revenues
Revenue from ethanol sales increased by approximately 50% during our 2011 fiscal year compared to our 2010 fiscal year. Revenue from distillers grains increased by approximately 66% during our 2011 fiscal year compared to our 2010 fiscal year. Revenue from corn oil increased by approximately 97% during our 2011 fiscal year compared to our 2010 fiscal year.
Ethanol
Our ethanol revenue increased by approximately $40.3 million during our 2011 fiscal year compared to our 2010 fiscal year, an increase of approximately 50%. This increase in ethanol revenue was due to an increase in the average price we received for our ethanol of approximately $0.74 per gallon, an increase of approximately 43%, during our 2011 fiscal year compared to our 2010 fiscal year. We also had an increase in total gallons of ethanol sold of approximately 2.2 million gallons, an increase of approximately 5%, during our 2011 fiscal year compared to our 2010 fiscal year.
Management attributes the increase in ethanol prices during our 2011 fiscal year with higher corn and energy prices along with increased ethanol demand from exports. The United States primarily exports ethanol to Brazil, the European Union and Canada. However, the European Union commenced an anti-dumping investigation with respect to the United States ethanol industry which may negatively impact ethanol exports to Europe going forward. The ethanol industry experienced a significant increase in ethanol demand in December 2011 related to the expiration of the VEETC blenders' credit. Management believes that many fuel blenders were increasing their ethanol purchases during December 2011 in order to take advantage of VEETC before it expired on December 31, 2011. Management also believes that this resulted in higher ethanol prices in December 2011. Following the end of our 2011 fiscal year, ethanol prices have decreased sharply which has resulted in tighter operating margins in the United States. Management anticipates continued tight operating margins in the beginning of our 2012 fiscal year but anticipates that ethanol prices will increase in the coming months as the surplus ethanol which was produced and sold in December 2011 is used which will allow the gap between ethanol supply and demand to narrow. Further, due to recent increases in gasoline prices, gasoline demand has been decreasing since the end of 2011. Since ethanol is typically blended with gasoline, when gasoline demand decreases it leads to a decrease in ethanol demand. Management believes that this decrease in gasoline demand has negatively impacted ethanol demand and prices. Management anticipates that we will produce and sell a comparable number of gallons of ethanol during our 2012 fiscal year compared to our 2011 fiscal year.
Management believes that the ethanol industry has reached what is typically referred to as the blending wall which is limiting domestic ethanol demand and prices. The blending wall is a theoretical limit to the amount of ethanol that can be used in the United States due to the fact that most ethanol is blended at a rate of 10% ethanol to 90% gasoline. Gasoline demand in the United States was approximately 130 billion gallons during 2011. Based on the blending wall concept, this would lead to approximately 13 billion gallons of ethanol demand. The blending wall does not take into account demand from exports and higher blends of ethanol such as E85 which includes up to 85% ethanol and 15% gasoline. Management believes that in order to expand demand for ethanol, the industry must expand the use of higher level blends of ethanol in standard vehicles. Recently, E15, a blend of 15% ethanol and 85% gasoline, was approved for use in all vehicles produced in the 2001 model year and later. However, the fact that E15 was not approved for use in all vehicles and other market and regulatory hurdles to the implementation of E15, management does not anticipate that E15 will be widely available in the market in the near term. Without increases in the allowed blends of ethanol for all standard vehicles, ethanol demand may continue to be limited by the blending wall. As the ethanol industry continues to hit the blending wall, ethanol prices and demand may not continue to increase.
The United States ethanol industry exported nearly 1 billion gallons of ethanol in 2011. This provided additional ethanol demand which helped to reduce the impact that the blending wall had on ethanol demand and prices. However, if ethanol exports decrease in the future, we may experience excess ethanol supply in the United States which could negatively impact the demand for ethanol and the prices we receive for the ethanol we produce.
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Distillers Grains
Our revenue from distillers grains increased significantly during our 2011 fiscal year compared to our 2010 fiscal year due primarily to increased corn prices. As the spread between market corn prices and market distillers grains prices increases, demand for distillers grains increases. Due to the higher corn prices during our 2011 fiscal year, we experienced higher distillers grains demand and prices.
We primarily market our distillers grains in the modified/wet form compared to dried distillers grains due to market conditions near our plant which favor the sale of distillers grains in the modified/wet form. Our revenue from the sale of modified/wet distillers grains increased by approximately $9.6 million, an increase of approximately 134%, during our 2011 fiscal year compared to our 2010 fiscal year. Our revenue from sales of dried distillers grains decreased by approximately $838,000, a decrease of approximately 14%, during our 2011 fiscal year compared to our 2010 fiscal year. We sold a comparable number of tons of distillers grains during our 2011 fiscal year compared to our 2010 fiscal year. However, the price we received per ton of distillers grains increased significantly for both our dried distillers grains and our modified/wet distillers grains. The average price we received per ton of dried distillers grains increased by approximately 60% during our 2011 fiscal year compared to our 2010 fiscal year. The average price we received per ton of modified/wet distillers grains increased by approximately 70% during our 2011 fiscal year compared to our 2010 fiscal year.
Distillers grains demand from exports was lower during 2011 compared to 2010 due to decreased exports to China. In late 2010, China started an anti-dumping investigation related to distillers grains exports from the United States. China was the largest importer of distillers grains from the United States during 2010. Despite the anti-dumping investigation, China was still the second leading importer of distillers grains produced in the United States during 2011. Further, domestic demand increases related to higher corn prices resulted in higher distillers grains prices during 2011 compared to 2010. Management anticipates continued high distillers grains prices in 2012 due to anticipated higher corn prices along with strong demand. Further, corn supply issues in foreign production markets may lead to continued tight corn supplies which may result in increased distillers grains demand and prices.
Corn Oil
As a result of higher corn prices, corn oil prices were higher during our 2011 fiscal year compared to our 2010 fiscal year. The average price we received per pound of corn oil increased by approximately $0.16 per pound, an increase of approximately 59%, during our 2011 fiscal year compared to our 2010 fiscal year. In addition, we sold approximately 1.6 million more pounds of corn oil, an increase of approximately 23%, during our 2011 fiscal year compared to our 2010 fiscal year. Management anticipates that corn oil prices will continue to remain high during our 2012 fiscal year due to higher corn prices and increased corn oil demand. Management anticipates that biodiesel demand will be higher during 2012 which will lead to increased demand for corn oil which can be used as a feedstock to produce biodiesel. Management anticipates that we will produce a comparable amount of corn oil during our 2012 fiscal year as compared to our 2011 fiscal year.
Government Incentives
We received less revenue from the State of South Dakota during our 2011 fiscal year compared to our 2010 fiscal year due to the State of South Dakota having less funding available to pay this incentive. We anticipate receiving an incentive payment for our 2011 production during 2012 due to this lack of funding availability in 2011.
Cost of Revenues
The primary raw materials we use to produce ethanol and distillers grains are corn and natural gas. Our cost of revenues was approximately 47% greater for our 2011 fiscal year compared to our 2010 fiscal year due to higher corn costs. Our average cost per bushel of corn increased by approximately 53% during our 2011 fiscal year compared to our 2010 fiscal year from approximately $3.91 per bushel in 2010 to approximately $6.00 per bushel during 2011. Management attributes this increase in corn costs with higher market corn prices due to decreased corn carryover from the 2010/2011 crop year. Management anticipates that the area surrounding the ethanol plant will continue to produce a significant amount of corn and that we will not have any difficulty securing the corn that we need to operate the ethanol plant. We consumed a comparable amount of corn in our operations during our 2011 fiscal year compared to our 2010 fiscal year. Management anticipates continued higher corn prices during our 2012 fiscal year due to strong corn demand. However, management anticipates that corn prices will remain volatile due to the effect that poor weather can have on corn prices along with continued uncertainty regarding whether corn carryover will continue to be tight between the current crop and the crop that will be harvested in the fall of 2012.
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Our cost of revenues related to natural gas decreased by approximately $597,000, a decrease of approximately 8%, during our 2011 fiscal year compared to our 2010 fiscal year. This decrease was due to a decrease in market natural gas prices during our 2011 fiscal year compared to our 2010 fiscal year. Our average cost per MMBtu of natural gas during our 2011 fiscal year was approximately 7% lower compared to our 2010 fiscal year, a decrease of approximately $0.36 per MMBtu of natural gas. Management attributes this decrease in natural gas prices to strong natural gas supplies and relatively stable natural gas demand. Management anticipates that natural gas prices will remain steady during our 2012 fiscal year unless natural gas production problems arise. Such production problems could arise due to hurricane activity in the Gulf Coast or due to reduced production of natural gas due to efforts to end the natural gas production process called hydraulic fracturing or "fracking." Some environmental groups have opposed fracking due to concerns regarding the environmental impact this process may have. If there is a ban or other regulatory action which reduces fracking, it could result in decreased natural gas production which could result in higher natural gas prices. In addition, some believe that due to the recent increase in natural gas production in the United States, in the future the United States will start exporting natural gas which could lead to higher natural gas prices.
We also used approximately 21,000 less MMBtu of natural gas during our 2011 fiscal year compared to our 2010 fiscal year, a decrease of approximately 2%. Management attributes this decrease in natural gas consumption with the reduction in the amount of dried distillers grains produced. Management anticipates that our natural gas consumption will be comparable during our 2012 fiscal year to our 2011 fiscal year due to anticipated levels of production at the ethanol plant.
Operating Expense
Our operating expenses were higher during our 2011 fiscal year compared to our 2010 fiscal year due to higher wages and benefits as well as higher bonus expenses during our 2011 fiscal year. We also had more environmental and public relations expenses during our 2011 fiscal year compared to our 2010 fiscal year.
Other Income and Expense
We had more interest income during our 2011 fiscal year compared to our 2010 fiscal year due to having more cash on hand during the 2011 period. We also had a gain of approximately $381,000 related to settlement of a lawsuit in which we were involved. We had less debt outstanding during our 2011 fiscal year compared to our 2010 fiscal year which led to a decrease in our interest expense. We had less equity in the income of our investments due to lower earnings from their operations.
Comparison of Fiscal Years Ended December 31, 2010 and 2009
The following table shows the results of our operations and the percentage of revenues, cost of revenues, operating expenses and other items to total revenues in our consolidated statements of operations for the fiscal years ended December 31, 2010 and 2009:
2010 | 2009 | |||||||||||||
Income Statement Data | Amount | % | Amount | % | ||||||||||
Revenue | $ | 96,395,789 | 100.0 | $ | 90,340,642 | 100.0 | ||||||||
Cost of Revenues | 86,289,732 | 89.5 | 81,659,486 | 90.4 | ||||||||||
Gross Profit | 10,106,057 | 10.5 | 8,681,156 | 9.6 | ||||||||||
Operating Expense | 2,922,059 | 3.0 | 2,957,809 | 3.3 | ||||||||||
Income from Operations | 7,183,998 | 7.5 | 5,723,347 | 6.3 | ||||||||||
Other Income (Expense) | (139,436 | ) | (0.1 | ) | (848,578 | ) | (0.9 | ) | ||||||
Net Income | $ | 7,044,562 | 7.3 | $ | 4,874,769 | 5.4 | ||||||||
Revenues
Revenue from ethanol sales increased by approximately 8% during our 2010 fiscal year compared to our 2009 fiscal year. Revenue from distillers grains decreased by approximately 6% during our 2010 fiscal year compared to our 2009 fiscal year. Revenue from corn oil increased by approximately 84% during our 2010 fiscal year compared to our 2009 fiscal year.
Ethanol
Our ethanol revenue increased by approximately $5.8 million during our 2010 fiscal year compared to our 2009 fiscal year, an increase of approximately 8%. This increase in ethanol revenue was due to an increase in the average price we received
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for our ethanol of approximately $0.16 per gallon, an increase of approximately 10%, during our 2010 fiscal year compared to our 2009 fiscal year. Management attributes this increase in ethanol prices with higher corn and energy prices during 2010.
Partially offsetting these higher ethanol prices was a decrease in our total ethanol sales of approximately 2%, or approximately 931,000 gallons. Management attributes this decrease in ethanol sales with decreased ethanol shipments at the end of our 2010 fiscal year. Our ethanol production was comparable in our 2010 and 2009 fiscal years.
Distillers Grains
We sold more of our distillers grains in the dried form during our 2010 fiscal year compared to our 2009 fiscal year. This change in the composition of our distillers grains sales was due to market conditions that favored the production and sale of dried distillers grains compared to modified/wet distillers grains. We increased sales of dried distillers grains by approximately 20%, or approximately 11,000 tons, during our 2010 fiscal year compared to our 2009 fiscal year. The average price we received per ton of dried distillers grains deceased by approximately 7%, or approximately $7.00 per ton, during our 2010 fiscal year compared to our 2009 fiscal year. We experienced relatively higher distillers grains prices during our 2009 fiscal year due to higher distillers grains demand and relatively lower supply during that time period. We sold approximately 8% less modified/wet distillers grains during our 2010 fiscal year compared to our 2009 fiscal year. In addition, the average price we received for our modified/wet distillers grains was approximately 10% lower during our 2010 fiscal year compared to our 2009 fiscal year. In real terms, this was a decrease of approximately $10 per ton.
Corn Oil
Our total pounds of corn oil sold increased by approximately 92% during our 2010 fiscal year compared to our 2009 fiscal year, primarily due to improved operation of the corn oil extraction equipment. In addition to the increase in corn oil sales, the average price we received for our corn oil increased by approximately 24% during our 2010 fiscal year compared to our 2009 fiscal year, an increase of approximately $0.05 per pound of corn oil sold due to higher corn prices and increased corn oil demand.
Government Incentives
During our 2010 fiscal year, we experienced a slight increase in our incentive revenue of less than $30,000 compared to our 2009 fiscal year. Management attributes this slight increase in incentive revenue during our 2010 fiscal year with more funds being available for the South Dakota program.
Cost of Revenues
The primary raw materials we use to produce ethanol and distillers grains are corn and natural gas. Our cost of revenues was approximately 6% greater for our 2010 fiscal year compared to our 2009 fiscal year due to higher corn costs. Our average cost per bushel of corn increased by approximately 10% during our 2010 fiscal year compared to our 2009 fiscal year from approximately $3.55 per bushel in 2009 to approximately $3.91 per bushel during 2010. Management attributes this increase in corn costs with higher market corn prices due to decreased corn carryover from the 2009/2010 crop year. In addition to the increase in corn costs per bushel, we used approximately 55,000 more bushels of corn, an increase of less than 1%, during our 2010 fiscal year compared to our 2009 fiscal year. Management attributes this increase in corn consumption with the fact that we ran the ethanol plant harder during 2010 in order to benefit from favorable economic conditions in the ethanol industry which led to slightly lower ethanol yields per bushel of corn.
Our cost of revenues related to natural gas decreased by approximately $922,000, a decrease of approximately 11%, during our 2010 fiscal year compared to our 2009 fiscal year. This decrease was due to a decrease in market natural gas prices during our 2010 fiscal year compared to our 2009 fiscal year. Our average cost per MMBtu of natural gas during our 2010 fiscal year was approximately 16% lower compared to our 2009 fiscal year, a decrease of approximately $1.00 per MMBtu of natural gas. Management attributes this decrease in natural gas prices to strong natural gas supplies and relatively stable natural gas demand.
Partially offsetting this decrease in natural gas costs per MMBtu was an increase in the total MMBtu of natural gas that we consumed during our 2010 fiscal year of approximately 71,000 MMBtu, an increase of approximately 5%, compared to our 2009 fiscal year. Management attributes this increase in natural gas consumption with increased production of dried distillers grains which require more natural gas to produce than modified/wet distillers grains because we use natural gas to fire our distillers grains dryers.
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Operating Expense
We did not experience any material changes in our operating expenses during our 2010 fiscal year compared to our 2009 fiscal year.
Other Income and Expense
Our other expense was significantly lower during our 2010 fiscal year compared to our 2009 fiscal year. We had less interest income during our 2010 fiscal year compared to our 2009 fiscal year because we had less cash on hand during the 2010 period. Our investments provided income during our 2010 fiscal year compared to a loss during our 2009 fiscal year. Finally, we paid significantly less interest during our 2010 fiscal year compared to our 2009 fiscal year due to our continuing retirement of our long-term debt.
Changes in Financial Condition for the Fiscal Year Ended December 31, 2011 Compared to the Fiscal Year Ended December 31, 2010.
Current Assets
We had significantly more cash on hand at December 31, 2011 compared to December 31, 2010 due to our increased net income and lower payments on our credit facilities during our 2011 fiscal year. We had significantly less cash due from our commodities broker due to having fewer derivative instrument positions that required us to maintain cash in our margin account.
Property and Equipment
The net book value of our equipment was lower at December 31, 2011 compared to December 31, 2010 as a result of proceeds from a litigation settlement from which we wrote off the remaining net book value of a piece of equipment and the remainder of the settlement was recorded as income. Our net property and equipment was lower at December 31, 2011 compared to December 31, 2010 as a result of this decrease in the net book value of our equipment along with depreciation. We did not make any significant capital expenditures during our 2011 fiscal year that increased the value of our property and equipment.
Other Assets
The value of our investments increased at December 31, 2011 compared to December 31, 2010 mainly due to earnings from our investment in RPMG, our ethanol, distillers grains and corn oil marketer.
Current Liabilities
We had no checks issued in excess of our bank balances at December 31, 2011 due to the significant amount of cash we had on hand at December 31, 2011. Our accounts payable was higher at December 31, 2011 compared to December 31, 2010 due an increase in the amount of corn expenditures payable. The unrealized liability associated with our risk management activities was lower at December 31, 2011 compared to December 31, 2010 because the market had fallen at the end of 2011 and minimized the liability of our position compared to the market rise at the end of 2010 which created a liability related to our position. We had no amounts outstanding on our short-term revolving line of credit as of December 31, 2011 compared to more than $1.8 million at December 31, 2010. The current portion of our long-term notes payable was significantly lower as of December 31, 2011 compared to December 31, 2010 because we repaid the subordinated notes we issued to certain individuals in early 2009 during our 2011 fiscal year. These subordinated notes were included in our current portion of notes payable as of December 31, 2010.
Long-Term Liabilities
Our notes payable, net of current portions, was lower at December 31, 2011 compared to December 31, 2010 because of the ongoing payments we have made on our land purchase promissory note and the subordinated debt we secured to pay for our corn oil extraction equipment. We included a long-term liability on our balance sheet in prior years associated with costs we anticipated to repair certain leased railcars. These costs were paid during our 2011 fiscal year.
Plant Operations
Management anticipates that the plant will continue to operate at or above name-plate capacity of 40 million gallons per year for the next twelve months. We expect to have sufficient cash from cash flow generated by our continuing operations, our
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debt financing and our cash reserves to cover the costs of operations over the next 12 months, which consist primarily of corn supply, natural gas supply, staffing, office, audit, legal, compliance, working capital costs and debt service obligations.
Liquidity and Capital Resources
Our main sources of liquidity are cash from our continuing operations and amounts we have available to draw on our revolving lines of credit. Management does not anticipate that we will need to raise additional debt or equity financing in the next twelve months and management believes that our current sources of liquidity will be sufficient to continue our operations during that time period. We do not anticipate making any significant capital expenditures in the next 12 months other than ordinary repair and replacement of equipment in our ethanol plant.
Currently, we have two revolving loans which allow us to borrow funds for working capital. These two revolving loans are described in greater detail below in the section entitled "Indebtedness." As of December 31, 2011, we had $0 outstanding and $15,000,000 available to be drawn on these revolving loans. Management anticipates that this is sufficient to maintain our liquidity and continue our operations. Our $10 million revolving line of credit expires in May 2012 and management anticipates that it will be renewed. However, if this revolving line of credit is not renewed, it would negatively impact our liquidity.
The following table shows a comparison of cash flows for the fiscal years ended December 31, 2011 and December 31, 2010:
Year ended December 31, | ||||||||
2011 | 2010 | |||||||
Net cash from operating activities | $ | 25,796,954 | $ | 5,017,112 | ||||
Net cash from (used for) investing activities | 961,189 | (63,601 | ) | |||||
Net cash used for financing activities | (16,170,288 | ) | (4,680,773 | ) | ||||
Cash Flow From Operations. Our operating activities provided more cash during our 2011 fiscal year compared to our 2010 fiscal year primarily due to our increased net income. We also experienced a significant increase in accounts payable during our 2011 fiscal year which positively impacted our cash flow.
Cash Flow From Investing Activities. Our investing activities provided cash due to a payment we received when we settled a prior legal dispute. This resulted in a $1 million payment which is subject to a confidential settlement agreement. We also used more cash for purchases of machinery and equipment and other assets during our 2011 fiscal year compared to our 2010 fiscal year.
Cash Flow From Financing Activities. We used more cash in our financing activities during our 2011 fiscal year compared to our 2010 fiscal year primarily due to larger payments we made on our credit facilities and a larger amount of distributions paid during our 2011 fiscal year compared to our 2010 fiscal year.
The following table shows a comparison of cash flows for the fiscal years ended December 31, 2010 and December 31, 2009:
Year ended December 31, | ||||||||
2010 | 2009 | |||||||
Net cash from operating activities | $ | 5,017,112 | $ | 2,015,584 | ||||
Net cash used for investing activities | (63,601 | ) | (1,033,331 | ) | ||||
Net cash used for financing activities | (4,680,773 | ) | (1,105,704 | ) | ||||
Cash Flow From Operations. Our operating activities provided more cash during our 2010 fiscal year compared to our 2009 fiscal year primarily due to our increased net income.
Cash Flow From Investing Activities. We used significantly less cash for investing activities during our 2010 fiscal year compared to our 2009 fiscal year due to decreased capital expenditures during 2010. During our 2009 fiscal year, we made capital expenditures related to our corn oil equipment. We also purchased other assets related to water supply contract rights during our 2010 fiscal year. We did not purchase any investments during our 2010 and 2009 fiscal years.
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Cash Flow From Financing Activities. We used more cash in our financing activities during our 2010 fiscal year compared to our 2009 fiscal year primarily due to a distribution we paid during our 2010 fiscal year along with less borrowing during our 2010 fiscal year compared to our 2009 fiscal year.
Indebtedness
First National Bank of Omaha (FNBO) is our primary lender. We have two loans outstanding with FNBO, a short-term revolving loan and a long-term revolving loan. In June 2011, we executed amendments to our FNBO revolving loans. The material terms of these loans, as amended, are described below.
We also have two loans that we used to finance the cost of our corn oil extraction equipment which totaled $1,200,000 and a loan related to a piece of property that we purchased adjacent to our ethanol plant. The specifics of each credit facility are discussed below.
Short-Term Debt Sources
We have a short-term revolving promissory note with FNBO that expires on May 1, 2012. The amount available under this short-term revolving promissory note is $10 million. However, the maximum amount we can draw on this short-term loan is limited by a borrowing base calculation, described in the June 2011 amendment, based on a percentage of our inventory and accounts receivable less certain accounts payable and letters of credit that we may have outstanding from time to time. We agreed to pay a variable interest rate on the revolving promissory note at an annual rate 350 basis points above the one month London Interbank Offered Rate (LIBOR), adjusted monthly. The revolving promissory note is subject to a minimum interest rate of 4.0% per year. The interest rate for this loan at December 31, 2011 was the minimum interest rate of 4.0%. We are required to pay a fee of 0.4% on the unused portion of the revolving promissory note. The revolving promissory note is collateralized by the ethanol plant, its accounts receivable and inventories. As of December 31, 2011, we had $0 outstanding on our revolving promissory note and $10,000,000 available to be drawn.
Long-Term Debt Sources
During our third quarter of 2010, we repaid our term note that was used for the permanent financing of the ethanol plant.
We restructured our long-term revolving loan that we refer to as Term Note 5 in June 2011. Term Note 5 was restructured into a $5,000,000 loan with an interest rate that accrues at 350 basis points above the one month LIBOR, adjusted monthly. Term Note 5 is subject to a minimum interest rate of 4.0% per year. The credit limit on Term Note 5 reduces each year by $500,000 until the maturity date on May 1, 2014. Therefore, the funds available for us to draw on Term Note 5 will decrease each year. If in any year we have a principal balance outstanding on Term Note 5 in excess of the new credit limit, we must make a payment to FNBO such that the amount outstanding on Term Note 5 does not exceed the new credit limit. We are required to pay a fee of 0.4% on the unused portion of Term Note 5. On December 31, 2011, we had $0 outstanding and $5,000,000 available to be drawn on this loan. As of December 31, 2011, interest accrued on Term Note 5 at the minimum interest rate of 4.0% per year.
We also have a long-term debt obligation related to our purchase of an additional 135 acres of land pursuant to a land purchase contract. This long-term debt obligation accrues interest at a fixed rate of 7%. The total cost of this additional land was $550,000. As of December 31, 2011, we had $112,500 remaining to be paid pursuant to this land purchase contract. This long-term debt obligation matures on December 1, 2012.
Subordinated Debt
During our 2009 fiscal year, we completed a private placement offering of subordinated unsecured debt securities. The debt securities that we offered were not registered with the Securities and Exchange Commission and were offered pursuant to claimed exemptions from registration under state and federal securities laws. We raised a total of $1,439,000 in subordinated debt through this offering. Interest on the subordinated notes accrued at a fixed interest rate of 9% per year. These subordinated debt securities had a two-year maturity from the date they were issued, with interest being paid on January 30th of each year and at maturity. We repaid the final subordinated unsecured debt securities during our second quarter of 2011, so as of December 31, 2011, the outstanding principal balance of our subordinated unsecured debt securities was $0.
In addition, on July 24, 2009, we entered into a $700,000 subordinated secured loan with Guardian Eagle Investments, LLC. The note accrued interest at a fixed rate of 9% per year and required monthly installments of principal and interest. This loan was scheduled to mature in April 2012. We repaid the balance of the Guardian Eagle loan in December 2010, therefore, the principal balance of the Guardian Eagle loan was $0 as of December 31, 2011.
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We raised a total of $1,200,000 in subordinated loans to help offset the cost of our corn oil extraction equipment from two different parties. We secured $1,000,000 in financing for the corn oil extraction equipment from the Rural Electric Economic Development, Inc. (REED) and $200,000 from the First District Development Company (FDDC). We closed on these loans on May 22, 2009. We agreed to pay 4.70% interest on the $1,000,000 loan from REED and 5.5% interest on the $200,000 FDDC loan. Both loans are amortized over a period of five years and both loans require monthly payments. The principal balance of the REED loan was approximately $513,000 as of December 31, 2011. The principal balance of the FDDC loan was approximately $104,000 as of December 31, 2011.
Covenants
Our credit facilities with FNBO are subject to various loan covenants. If we fail to comply with these loan covenants, FNBO can declare us to be in default of our loans. The material loan covenants applicable to our credit facilities are our fixed charge coverage ratio, our minimum net worth and minimum working capital requirements. We are required to maintain a fixed charge coverage ratio of no less than 1.10 to 1.0. This fixed charge coverage ratio compares our EBITDA adjusted earnings, as defined in our credit agreements, with our scheduled principal and interest payments on our outstanding debt obligations, including our subordinated debt. We are also required to maintain at least $4.8 million in working capital and maintain minimum net worth of $20 million.
As of December 31, 2011, we were in compliance with all of our loan covenants. Management's current financial projections indicate that we will be in compliance with our financial covenants for the next 12 months and we expect to remain in compliance thereafter. Management does not believe that it is reasonably likely that we will fall out of compliance with our material loan covenants in the next 12 months. If we fail to comply with the terms of our credit agreements with FNBO, and FNBO refuses to waive the non-compliance, FNBO may require us to immediately repay all amounts outstanding on our loans.
Lake County Tax Increment Financing Bonds
We have a guarantee obligation on a portion of a $1.323 million tax increment revenue bond series issued by Lake County, South Dakota on December 2, 2003. The portion for which we are obligated is estimated at approximately $95,000. The bond was issued in connection with the refunding of a tax increment financing bond issued by Lake County in 2001, of which we were the recipient of the proceeds. In 2003, Lake County became aware that the taxes collected from the property on which the plant is located would be insufficient to cover the debt service of the 2001 bond issue. Based on this deficiency and changes in interest rates during December 2003, Lake County refunded the 2001 bond issue and replaced it with two separate bonds: a tax-exempt bond in the amount of $824,599 and a taxable bond in the amount of $1,323,024. As a part of this refund, we entered into an agreement with the holder of these bonds to guarantee the entire debt service on the taxable bond issue. The taxes levied on our property are used first towards paying the debt service of the tax-exempt bonds and any remaining taxes are used for paying the debt service of the taxable bonds. Since the property taxes on the property are currently sufficient to cover a portion of the debt service on the taxable bond series, our obligation under the guarantee is to cover the shortfall in debt service, representing the difference between the original taxable bond amount ($1,323,024) and the estimated amount expected to be collected in property taxes from the real property on which our plant is located. The interest rate on the bonds is 7.75% annually. The taxable bonds require semi-annual payments of interest on December 1 and June 1, in addition to a payment of principal on December 1 of each year. While our obligation under the guarantee is expected to continue until maturity in 2018, such obligation may cease at some point in time if the property on which the plant is located appreciates in value to the extent that Lake County is able to collect a sufficient amount in taxes to cover the principal and interest payments on the taxable bonds. The principal balance outstanding was approximately $799,000 as of December 31, 2011.
In addition to our debt obligations, we have certain other contractual cash obligations and commitments. The following table provides information regarding our consolidated contractual obligations and commitments as of December 31, 2011:
29
Payment Due By Period | ||||||||||||||||||||
Contractual Cash Obligations | Total | Less than One Year | One to Three Years | Three to Five Years | After Five Years | |||||||||||||||
Long-Term Debt Obligations | $ | 833,655 | $ | 387,489 | $ | 432,458 | $ | 13,708 | $ | — | ||||||||||
Estimated Interest on Long-Term Debt | 55,542 | 37,122 | 18,248 | 172 | — | |||||||||||||||
Operating Lease Obligations | — | — | — | — | — | |||||||||||||||
Purchase Obligations | 28,038,495 | 28,038,495 | — | — | — | |||||||||||||||
Other Long-Term Liabilities | 95,411 | 52,145 | 38,463 | 4,803 | — | |||||||||||||||
Total Contractual Cash Obligations | $ | 29,023,103 | $ | 28,515,251 | $ | 489,169 | $ | 18,683 | $ | — | ||||||||||
Application of Critical Accounting Policies
Management uses estimates and assumptions in preparing our consolidated 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 consolidated financial statements, we believe that the following are the most critical:
Derivative Instruments
We enter into short-term forward, option and futures contracts as a means of securing corn and natural gas for the ethanol plant and managing exposure to changes in commodity and energy prices. We enter into short-term forward, option and futures contracts for sales of ethanol to manage exposure to changes in energy prices. All of our derivatives are designated as non-hedge derivatives, and accordingly are recorded at fair value with changes in fair value recognized in net income. Although the contracts are considered economic hedges of specified risks, they are not designated as and accounted for as hedging instruments.
As part of our trading activity, we use futures and option contracts offered through regulated commodity exchanges to reduce our risk and we are exposed to risk of loss in the market value of inventories. To reduce that risk, we generally take positions using futures contracts and options.
Unrealized gains and losses related to derivative contracts for corn and natural gas purchases are included as a component of cost of revenues and derivative contracts related to ethanol sales are included as a component of revenues in the accompanying financial statements. The fair values of derivative contracts are presented on the accompanying balance sheet as derivative financial instruments.
Goodwill
We record as goodwill the excess of purchase price over the fair value of the identifiable net assets acquired. Annually, as well as when an event triggering impairment may have occurred, the Company is required to perform an impairment test on goodwill. The first step tests for impairment, while the second step, if necessary, measures the impairment. We perform our annual analysis on December 31 of each fiscal year. We determined that there was no impairment to our goodwill at December 31, 2011 or 2010.
Revenue Recognition
Revenue from the sale of our products is recognized at the time title to the goods and all risks of ownership transfer to the customers. The time of transfer is defined in the specific sales agreement; however, it generally occurs upon shipment, loading of the goods or when the customer picks up the goods. Collectability of revenue is reasonably assured based on historical evidence of collectability between us and our customers. Interest income is recognized as earned.
Shipping costs incurred by us in the sale of ethanol and corn oil are not specifically identifiable and as a result, revenue from the sale of ethanol and corn oil are recorded based on the net selling price reported to us from our marketer. Shipping costs incurred by us in the sale of distiller grain products are included in cost of goods sold.
Off-Balance Sheet Arrangements
We do not have any off-balance sheet arrangements.
30
ITEM 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
We are exposed to the impact of market fluctuations associated with commodity prices as discussed below. We have no exposure to foreign currency risk as all of our business is conducted in U.S. Dollars. 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 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 SFAS 133, Accounting for Derivative Instruments and Hedging Activities.
Commodity Price Risk
We are exposed to market risk from changes in commodity prices. Exposure to commodity price risk results from our dependence on corn and natural gas in the ethanol production process. We seek to minimize the risks from fluctuations in the prices of corn and natural gas through the use of hedging instruments. 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, they are not designated as such for hedge accounting purposes, which would match the gain or loss on our hedge positions to the specific commodity purchase being hedged. We are marking to market our hedge positions, which means as the current market price of our hedge positions changes, the gains and losses are immediately recognized in our cost of revenues.
The immediate recognition of hedging gains and losses 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. We recorded an increase to our cost of revenues of approximately $3.3 million related to derivative instruments for the year ended December 31, 2011. We recorded an increase to our cost of revenues of approximately $6.8 million related to derivative instruments for the year ended December 31, 2010. We recorded a decrease to cost of revenue of approximately $3.5 million related to our derivative instruments for our fiscal year ended December 31, 2009. There are several variables that could affect the extent to which our derivative instruments are impacted by price fluctuations in the cost of corn or natural gas. However, it is likely that commodity cash prices will have the greatest impact on the derivatives instruments with delivery dates nearest the current cash price.
As of December 31, 2011, we had price protection for approximately 14% of our expected corn usage for fiscal year ended December 31, 2012 using CBOT futures and options and over-the-counter option contracts. 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 to our financial results, but are designed to produce long-term positive growth for us.
As of December 31, 2011, we were committed to purchasing approximately 180,000 MMBtus of natural gas during our 2012 fiscal year, valued at approximately $369,000. The natural gas purchases represent approximately 13% of the annual plant requirements.
A sensitivity analysis has been prepared to estimate our exposure to ethanol, corn and natural gas price risk. Market risk related to these factors is estimated as the potential change in income resulting from a hypothetical 10% adverse change in the average cost of our corn and natural gas prices and average ethanol price as of December 31, 2011, net of the forward and future contracts used to hedge our market risk for corn and natural gas usage requirements. The volumes are based on our expected use and sale of these commodities for a one year period from December 31, 2011. The results of this analysis, which may differ from actual results, are as follows:
Estimated Volume Requirements for the next 12 months (net of forward and futures contracts) | Unit of Measure | Hypothetical Adverse Change in Price | Approximate Adverse Change to Income | ||||||||
Ethanol | 49,000,000 | Gallons | 10 | % | $ | 10,192,000 | |||||
Corn | 15,065,059 | Bushels | 10 | % | $ | 9,340,337 | |||||
Natural Gas | 1,220,000 | MMBTU | 10 | % | $ | 435,540 | |||||
For comparison purposes, our sensitivity analysis for our 2010 fiscal year is set forth below.
31
Estimated Volume Requirements for the next 12 months (net of forward and futures contracts) | Unit of Measure | Hypothetical Adverse Change in Price | Approximate Adverse Change to Income | ||||||||
Ethanol | 49,000,000 | Gallons | 10 | % | $ | 11,123,000 | |||||
Corn | 16,431,244 | Bushels | 10 | % | $ | 9,201,497 | |||||
Natural Gas | 1,280,000 | MMBTU | 10 | % | $ | 587,520 | |||||
32
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA
REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM
To the Board of Managers and Members
Lake Area Corn Processors, LLC
We have audited the accompanying consolidated balance sheets of Lake Area Corn Processors, LLC and subsidiary as of December 31, 2011 and 2010, and the related consolidated statements of income, changes in members' equity, and cash flows for each of the three years in the period ended December 31, 2011. These financial statements are the responsibility of the Company's management. Our responsibility is to express an opinion on these financial statements based on our audits.
We conducted our audits in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. The Company is not required to have, nor were we engaged to perform an audit of its internal control over financial reporting. Our 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 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 Lake Area Corn Processors, LLC and subsidiary as of December 31, 2011 and 2010, and the results of their operations and their cash flows for each of the three years in the period ended December 31, 2011, in conformity with U.S. generally accepted accounting principles.
/s/ McGladrey & Pullen, LLP
Des Moines, Iowa
March 23, 2012
33
LAKE AREA CORN PROCESSORS, LLC
CONSOLIDATED BALANCE SHEETS
December 31, 2011 | December 31, 2010 | ||||||
ASSETS | |||||||
CURRENT ASSETS | |||||||
Cash and cash equivalents | $ | 11,225,659 | $ | 637,804 | |||
Accounts receivable | 4,259,385 | 4,114,940 | |||||
Other receivables | 172,296 | 188,959 | |||||
Inventory | 10,680,451 | 10,063,208 | |||||
Due from broker | 907,349 | 3,725,998 | |||||
Derivative financial instruments | 29,263 | 73,800 | |||||
Prepaid expenses | 126,031 | 126,523 | |||||
Total current assets | 27,400,434 | 18,931,232 | |||||
PROPERTY AND EQUIPMENT | |||||||
Land | 676,097 | 676,097 | |||||
Land improvements | 2,665,358 | 2,665,358 | |||||
Buildings | 8,088,853 | 8,088,853 | |||||
Equipment | 39,097,266 | 40,799,589 | |||||
50,527,574 | 52,229,897 | ||||||
Less accumulated depreciation | (24,053,888 | ) | (22,469,329 | ) | |||
Net property and equipment | 26,473,686 | 29,760,568 | |||||
OTHER ASSETS | |||||||
Goodwill | 10,395,766 | 10,395,766 | |||||
Investments | 2,972,091 | 2,856,445 | |||||
Other | 150,875 | 234,410 | |||||
Total other assets | 13,518,732 | 13,486,621 | |||||
TOTAL ASSETS | $ | 67,392,852 | $ | 62,178,421 | |||
See Notes to Consolidated Financial Statements.
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LAKE AREA CORN PROCESSORS, LLC
CONSOLIDATED BALANCE SHEETS
December 31, 2011 | December 31, 2010 | ||||||
LIABILITIES AND MEMBERS’ EQUITY | |||||||
CURRENT LIABILITIES | |||||||
Outstanding checks in excess of bank balance | $ | — | $ | 584,412 | |||
Accounts payable | 10,778,861 | 5,377,598 | |||||
Accrued liabilities | 763,526 | 672,802 | |||||
Derivative financial instruments | 1,226,705 | 2,527,175 | |||||
Short-term notes payable | — | 1,872,000 | |||||
Current portion of guarantee payable | 52,145 | 52,382 | |||||
Current portion of notes payable | 387,489 | 1,813,494 | |||||
Total current liabilities | 13,208,726 | 12,899,863 | |||||
LONG-TERM LIABILITIES | |||||||
Notes payable, net of current maturities | 446,166 | 833,655 | |||||
Guarantee payable, net of current portion | 43,266 | 95,411 | |||||
Other | — | 252,344 | |||||
Total long-term liabilities | 489,432 | 1,181,410 | |||||
COMMITMENTS AND CONTINGENCIES | |||||||
MEMBERS’ EQUITY (29,620,000 units issued and outstanding) | 53,694,694 | 48,097,148 | |||||
TOTAL LIABILITIES AND MEMBERS' EQUITY | $ | 67,392,852 | $ | 62,178,421 | |||
See Notes to Consolidated Financial Statements.
35
LAKE AREA CORN PROCESSORS, LLC
CONSOLIDATED STATEMENTS OF INCOME
December 31, 2011 | December 31, 2010 | December 31, 2009 | |||||||||
REVENUES | $ | 146,964,854 | $ | 96,395,789 | $ | 90,340,642 | |||||
COSTS OF REVENUES | 126,626,536 | 86,289,732 | 81,659,486 | ||||||||
GROSS PROFIT | 20,338,318 | 10,106,057 | 8,681,156 | ||||||||
OPERATING EXPENSES | 3,246,368 | 2,922,059 | 2,957,809 | ||||||||
INCOME FROM OPERATIONS | 17,091,950 | 7,183,998 | 5,723,347 | ||||||||
OTHER INCOME (EXPENSE) | |||||||||||
Interest and other income | 420,420 | 31,379 | 106,854 | ||||||||
Equity in net income of investments | 115,646 | 230,466 | (161,774 | ) | |||||||
Interest expense | (182,470 | ) | (401,281 | ) | (793,658 | ) | |||||
Total other income (expense) | 353,596 | (139,436 | ) | (848,578 | ) | ||||||
NET INCOME | $ | 17,445,546 | $ | 7,044,562 | $ | 4,874,769 | |||||
BASIC AND DILUTED EARNINGS PER UNIT | $ | 0.59 | $ | 0.24 | $ | 0.16 | |||||
WEIGHTED AVERAGE NUMBER OF UNITS OUTSTANDING FOR THE CALCULATION OF BASIC & DILUTED EARNINGS PER UNIT | 29,620,000 | 29,620,000 | 29,620,000 | ||||||||
See Notes to Consolidated Financial Statements.
36
LAKE AREA CORN PROCESSORS, LLC
CONSOLIDATED STATEMENTS OF CHANGES IN MEMBERS' EQUITY
YEARS ENDED DECEMBER 31, 2011, 2010 AND 2009
Members' | ||||
Equity | ||||
Balance, December 31, 2008 | $ | 38,859,138 | ||
Net Income | 4,874,769 | |||
Balance, December 31, 2009 | $ | 43,733,907 | ||
Net income | 7,044,562 | |||
Equity adjustment in investee | 280,679 | |||
Distributions paid ($.10 per capital unit) | (2,962,000 | ) | ||
Balance, December 31, 2010 | $ | 48,097,148 | ||
Net income | 17,445,546 | |||
Distributions paid ($.40 per capital unit) | (11,848,000 | ) | ||
Balance, December 31, 2011 | $ | 53,694,694 | ||
See Notes to Consolidated Financial Statements.
37
LAKE AREA CORN PROCESSORS, LLC
CONSOLIDATED STATEMENTS OF CASH FLOWS
December 31, 2011 | December 31, 2010 | December 31, 2009 | ||||||||
OPERATING ACTIVITIES | ||||||||||
Net income | $ | 17,445,546 | $ | 7,044,562 | 4,874,769 | |||||
Changes to net income not affecting cash and cash equivalents | ||||||||||
Depreciation and amortization | 2,744,683 | 2,759,379 | 2,775,009 | |||||||
Equity in net (income) loss of investments | (115,646 | ) | (230,466 | ) | 161,774 | |||||
Unrealized loss on purchase commitments | — | — | (2,735,966 | ) | ||||||
Lower of cost or market adjustment on inventory | — | — | 211,935 | |||||||
Gain on litigation settlement | (380,994 | ) | — | — | ||||||
Loss on sale of property and equipment | 45,539 | — | — | |||||||
(Increase) decrease in | ||||||||||
Receivables | (127,782 | ) | (571,246 | ) | (796,528 | ) | ||||
Inventory | (617,243 | ) | (2,483,034 | ) | (1,265,132 | ) | ||||
Prepaid expenses | 492 | 41,431 | 121,490 | |||||||
Derivative financial instruments and due from broker | 1,562,716 | (388,961 | ) | (608,201 | ) | |||||
Increase (decrease) in | ||||||||||
Accounts payable | 5,401,263 | (867,820 | ) | (1,209,677 | ) | |||||
Accrued and other liabilities | (161,620 | ) | (286,733 | ) | 486,111 | |||||
NET CASH PROVIDED BY OPERATING ACTIVITIES | 25,796,954 | 5,017,112 | 2,015,584 | |||||||
INVESTING ACTIVITIES | ||||||||||
Purchase of property and equipment | (38,811 | ) | (31,325 | ) | (1,033,331 | ) | ||||
Purchase of other assets | — | (32,276 | ) | — | ||||||
Proceeds from Litigation settlement | 1,000,000 | — | — | |||||||
NET CASH PROVIDED BY (USED IN) INVESTING ACTIVITIES | 961,189 | (63,601 | ) | (1,033,331 | ) | |||||
FINANCING ACTIVITIES | ||||||||||
Increase (decrease) in outstanding checks in excess of bank balance | (584,412 | ) | 298,608 | (115,114 | ) | |||||
Short-term notes payable issued | — | 1,872,000 | — | |||||||
Long-term notes payable issued | — | — | 3,339,000 | |||||||
Principal payments on short-term notes payable | (1,872,000 | ) | — | — | ||||||
Principal payments on long-term notes payable | (1,865,876 | ) | (3,889,381 | ) | (4,329,590 | ) | ||||
Distributions paid to LACP members | (11,848,000 | ) | (2,962,000 | ) | — | |||||
NET CASH USED FOR FINANCING ACTIVITIES | (16,170,288 | ) | (4,680,773 | ) | (1,105,704 | ) | ||||
NET INCREASE (DECREASE) IN CASH | 10,587,855 | 272,738 | (123,451 | ) | ||||||
CASH AND CASH EQUIVALENTS AT BEGINNING OF PERIOD | 637,804 | 365,066 | 488,517 | |||||||
CASH AND CASH EQUIVALENTS AT END OF PERIOD | $ | 11,225,659 | $ | 637,804 | 365,066 | |||||
SUPPLEMENTAL DISCLOSURES OF CASH FLOW INFORMATION | ||||||||||
Cash paid during the period for interest | $ | 302,707 | $ | 487,277 | 707,119 | |||||
SUPPLEMENTAL SCHEDULE OF NONCASH OPERATING AND FINANCING ACTIVITIES | ||||||||||
Other assets acquired through issuance of note payable | $ | — | $ | 147,102 | — | |||||
Equity adjustment in investee | $ | — | 280,679 | — | ||||||
See Notes to Consolidated Financial Statements
38
LAKE AREA CORN PROCESSORS, LLC
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
DECEMBER 31, 2011, 2010 AND 2009
NOTE 1 . NATURE OF OPERATIONS
Principal Business Activity
Lake Area Corn Processors, LLC and subsidiary (the Company) is a South Dakota limited liability company located in Wentworth, South Dakota. The Company was organized by investors to provide a portion of the corn supply for a 40 million-gallon (annual capacity) ethanol plant, owned by Dakota Ethanol, LLC (Dakota Ethanol). The Company sells ethanol and related products to customers located in North America.
NOTE 2. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
Principles of Consolidation
The consolidated financial statements of the Company include the accounts of its wholly owned subsidiary, Dakota Ethanol. All significant inter-company transactions and balances have been eliminated in consolidation.
Revenue Recognition
Revenue from the production of ethanol and related products is recorded when title transfers to customers. Generally, ethanol and related products are shipped FOB shipping point, based on written contract terms between Dakota Ethanol and its customers. Collectability of revenue is reasonably assured based on historical evidence of collectability between Dakota Ethanol and its customers. Interest income is recognized as earned.
Shipping costs incurred by the Company in the sale of ethanol, dried distiller's grains and corn oil are not specifically identifiable and as a result, revenue from the sale of those products is recorded based on the net selling price reported to the Company from the marketer.
Cost of Revenues
The primary components of cost of revenues from the production of ethanol and related co-product are corn expense, energy expense (natural gas and electricity), raw materials expense (chemicals and denaturant), and direct labor costs.
Shipping costs on modified and wet distiller's grains are included in cost of revenues. Shipping costs were approximately $1,025,000, $629,000, and $795,000, for the years ended December 31, 2011, 2010 and 2009, respectively.
Inventory Valuation
Ethanol inventory, raw materials, work-in-process, and parts inventory are valued using methods which approximate the lower of cost (first-in, first-out) or market. Distillers grains and related products are stated at net realizable value. In the valuation of inventories and purchase and sale commitments, market is based on current replacement values except that it does not exceed net realizable values and is not less than net realizable values reduced by allowances for approximate normal profit margin.
Cash and Cash Equivalents
Cash and cash equivalents consist of demand accounts and other accounts that provide withdrawal privileges. Checks drawn in excess of bank balance are recorded as a liability on the balance sheet and as a financing activity on the statement of cash flows.
Receivables and Credit Policies
Trade receivables are uncollateralized customer obligations due under normal trade terms requiring payment within fifteen days from the invoice date. Unpaid trade receivables with invoice dates over thirty days old bear interest at 1.5 percent per month. Trade receivables are stated at the amount billed to the customer. Payments of trade receivables are allocated to the specific invoices identified on the customer's remittance advice or, if unspecified, are applied to the earliest unpaid invoices.
39
LAKE AREA CORN PROCESSORS, LLC
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
DECEMBER 31, 2011, 2010 AND 2009
The carrying amount of trade receivables is reduced by a valuation allowance that reflects management's best estimate of the amounts that will not be collected. Management reviews all trade receivable balances that exceed sixty days from the invoice date and based on an assessment of current creditworthiness, estimates the portion, if any, of the balance that will not be collected.
Investment in commodities contracts, derivative instruments and hedging activities
The Company is exposed to certain risks related to our ongoing business operations. The primary risks that we manage by using forward or derivative instruments are price risk on anticipated purchases of corn, natural gas and the sale of ethanol.
The Company is subject to market risk with respect to the price and availability of corn, the principal raw material we use to produce ethanol and ethanol by-products. In general, rising corn prices result in lower profit margins and, therefore, represent unfavorable market conditions. This is especially true when market conditions do not allow us to pass along increased corn costs to our customers. The availability and price of corn is subject to wide fluctuations due to unpredictable factors such as weather conditions, farmer planting decisions, governmental policies with respect to agriculture and international trade and global demand and supply.
Certain contracts that literally meet the definition of a derivative may be exempted from derivative accounting as normal purchases or normal sales. Normal purchases and normal sales are contracts that provide for the purchase or sale of something other than a financial instrument or derivative instrument that will be delivered in quantities expected to be used or sold over a reasonable period in the normal course of business. Contracts that meet the requirements of normal purchases or sales are documented as normal and exempted from the accounting and reporting requirements of derivative accounting. For transactions initiated prior to January 1, 2011, we applied the normal purchase and sales exemption under derivative accounting for forward purchases of corn and sales of distiller's grains. We are choosing not to exempt corn purchase contracts initiated after December 31, 2010 from the derivative accounting and reporting requirements. As of December 31, 2011, we are committed to purchasing 4.1 million bushels of corn on a forward contract basis with an average price of $6.49 per bushel, of which 4.1 million bushels are subject to derivative accounting treatment and 40,000 bushels are accounted for as normal purchases, and accordingly, are not marked to market and are accounted for using lower of cost or market accounting. Dakota Ethanol has a derivative financial instrument liability of approximately $1.2 million related to the forward contracted purchases of corn. The total corn purchase contracts represent 24% of the annual plant corn usage.
The Company enters into firm-price purchase commitments with some of our natural gas suppliers under which we agree to buy natural gas at a price set in advance of the actual delivery of that natural gas to us. Under these arrangements, we assume the risk of a price decrease in the market price of natural gas between the time this price is fixed and the time the natural gas is delivered. At December 31, 2011, we are committed to purchasing 180,000 MMBtu's of natural gas with an average price of $3.55 per MMBtu. The Company accounts for these transactions as normal purchases, and accordingly, do not mark these transactions to market. The natural gas purchases represent approximately 13% of the annual plant requirements.
The Company enters into short-term forward, option and futures contracts for corn and natural gas as a means of managing exposure to changes in commodity and energy prices. The Company enters into short-term forward, option and futures contracts for sales of ethanol to manage exposure to changes in energy prices. All of our derivatives are designated as non-hedge derivatives, and accordingly are recorded at fair value with changes in fair value recognized in net income. Although the contracts are considered economic hedges of specified risks, they are not designated as and accounted for as hedging instruments.
As part of our trading activity, The Company uses futures and option contracts offered through regulated commodity exchanges to reduce risk and we are exposed to risk of loss in the market value of inventories. To reduce that risk, we generally take positions using forward and futures contracts and options.
Derivatives not designated as hedging instruments at December 31, 2011 and December 31, 2010 were as follows:
40
LAKE AREA CORN PROCESSORS, LLC
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
DECEMBER 31, 2011, 2010 AND 2009
Balance Sheet Classification | December 31, 2011 | December 31, 2010 | ||||||||
Forward contracts | Current Assets | $ | 38,213 | $ | 73,800 | |||||
Futures and options contracts | Current Assets | $ | 1,012,825 | $ | — | |||||
Forward contracts | (Current Liabilities) | $ | (1,264,918 | ) | $ | — | ||||
Futures and options contracts | (Current Liabilities) | $ | (983,562 | ) | $ | (2,527,175 | ) | |||
Realized and unrealized gains and losses related to derivative contracts related to corn and natural gas purchases are included as a component of cost of revenues and derivative contracts related to ethanol sales are included as a component of revenues in the accompanying financial statements.
Statement of Operations | Years Ended December 31, | |||||||||||||
Classification | 2011 | 2010 | 2009 | |||||||||||
Net realized and unrealized gains (losses) related to sales contracts: | ||||||||||||||
Futures and options contracts | Revenues | $ | — | $ | 252,938 | $ | (1,487,368 | ) | ||||||
Net realized and unrealized gains (losses) related to purchase contracts: | ||||||||||||||
Futures and options contracts | Cost of Revenues | $ | (42,211 | ) | $ | (6,912,347 | ) | $ | 720,608 | |||||
Forward contracts | Cost of Revenues | $ | (3,230,710 | ) | $ | 133,371 | $ | 2,774,307 | ||||||
Investments
Dakota Ethanol has investment interests in two unlisted companies in related industries. These investments are flow-through entities and are being accounted for by the equity method of accounting under which the Company's share of net income is recognized as income in the Company's income statement and added to the investment account. Distributions or dividends received from the investments are treated as a reduction of the investment account. The Company consistently follows the practice of recognizing the net income based on the most recent reliable data.
Dakota Ethanol has a seven percent investment interest in the company's ethanol marketer, Renewable Products Marketing Group, LLC (RPMG). The net income which is reported in the Company's income statement for RPMG is based on RPMG's September 30, 2011 audited results. The carrying amount of the Company's investment was approximately $1,973,000 and $1,863,000 as of December 31, 2011 and 2010, respectively.
Dakota Ethanol has a ten percent investment interest in Prairie Gold Venture Partnership, LLC (PGVP), a venture capital fund investing in cellulosic ethanol production. The net income which is reported in the Company's income statement for PGVP is based on PGVP's June 30, 2011 interim results. The carrying amount of the Company's investment was approximately $999,000 and $994,000 as of December 31, 2011 and 2010, respectively.
Use of Estimates
The preparation of financial statements in conformity with accounting principles generally accepted in the United States of America requires management to make estimates and assumptions that affect the reported amount of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and revenues and expenses during the reporting period. Actual results could differ from those estimates.
41
LAKE AREA CORN PROCESSORS, LLC
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
DECEMBER 31, 2011, 2010 AND 2009
Concentrations of Credit Risk
The Company's cash balances are maintained in bank depositories and regularly exceed federally insured limits. The company has not experienced any losses in connection with these balances.
Property and Equipment
Property and equipment is stated at cost. Significant additions and betterments are capitalized, while expenditures for maintenance, repairs and minor renewals are charged to operations when incurred. Depreciation on assets placed in service is computed using the straight-line method over estimated useful lives as follows:
Land improvements | 40 years |
Equipment | 5-20 years |
Buildings | 40 years |
Equipment relates to two general categories: mechanical equipment and administrative and maintenance equipment. Mechanical equipment generally relates to equipment for handling inventories and the production of ethanol and related products, with useful lives of 15 to 20 years, including boilers, cooling towers, grain bins, centrifuges, conveyors, fermentation tanks, pumps and drying equipment. Administrative and maintenance equipment is equipment with useful lives of 5 to 15 years, including vehicles, computer systems, security equipment, testing devices and shop equipment.
The Company reviews its property and equipment for impairment whenever events indicate that the carrying amount of the asset may not be recoverable. An impairment loss is recorded when the sum of the future cash flows is less than the carrying amount of the asset. An impairment loss is measured as the amount by which the carrying amount of the asset exceeds its fair value. No impairment has been identified.
Goodwill
Goodwill is not amortized but is subject to annual impairment tests. The Company has performed the required impairment tests as of December 31, 2011, which have resulted in no impairment adjustments.
Earnings Per Unit
For purposes of calculating basic earnings per unit, units issued are considered outstanding on the effective date of issuance. Diluted earnings per unit are calculated by including dilutive potential equity units in the denominator. There were no dilutive equity units for the years ending December 31, 2011, 2010, and 2009.
Income Taxes
The Company is taxed as a limited liability company under the Internal Revenue Code. The income of the Company flows through to the members to be taxed at the member level rather than the corporate level. Accordingly, the Company has no tax liability.
Management has evaluated the Company's tax positions under the Financial Accounting Standards Board issued guidance on accounting for uncertainty in income taxes and concluded that the Company had taken no uncertain tax positions that require adjustment to the financial statements to comply with the provisions of this guidance. Generally, the Company is no longer subject to income tax examinations by the U.S. federal, state or local authorities for the years before 2008.
Environmental Liabilities
Dakota Ethanol's operations are subject to environmental laws and regulations adopted by various governmental authorities in the jurisdiction in which it operates. These laws require Dakota Ethanol to investigate and remediate the effects of the release or disposal of materials at its locations. Accordingly, Dakota Ethanol has adopted policies, practices and procedures in the areas of
42
LAKE AREA CORN PROCESSORS, LLC
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
DECEMBER 31, 2011, 2010 AND 2009
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 Dakota Ethanol's liability is probable and the costs can be reasonably estimated.
Operating Segment
The Company uses the “management approach” for reporting information about segments in annual and interim financial statements. The management approach is based on the way the chief operating decision-maker organizes segments within a company for making operating decisions and assessing performance. Reportable segments are based on products and services, geography, legal structure, management structure and any other manner in which management disaggregates a company. Based on the “management approach” model, the Company has determined that its business is comprised of a single operating segment.
Recently Issued Accounting Pronouncements
ASU 2010-06, Fair Value Measurements and Disclosures (Topic 820) - Improving Disclosures about Fair Value Measurements. This ASU affects all entities that are required to make disclosures about recurring and nonrecurring fair value measurements under FASB ASC Topic 820, originally issued as FASB Statement No. 157, Fair Value Measurements. The ASU requires certain new disclosures and clarifies two existing disclosure requirements. The new disclosures and clarifications of existing disclosures are effective for interim and annual reporting periods beginning after December 15, 2009, except for the disclosures about purchases, sales, issuances, and settlements in the roll forward of activity in Level 3 fair value measurements. Those disclosures are effective for fiscal years beginning after December 15, 2010, and for interim periods within those fiscal years.
ASU 2011-04, Fair Value Measurement (Topic 820) - Amendments to Achieve Common Fair Value Measurement and Disclosure Requirements in U.S. GAAP and IFRSs. This ASU supersedes most of the guidance in Topic 820, although many of the changes are clarifications of existing guidance or wording changes to align with IFRS 13. In addition, certain amendments in ASU 2011-04 change a particular principle or requirement for measuring fair value or disclosing information about fair value measurements. The amendments in ASU 2011-04 are effective for public entities for interim and annual periods beginning after December 15, 2011.
ASU 2011-08, Intangibles - Goodwill and Other (Topic 350): Testing Goodwill for Impairment. This ASU gives an entity the option in its annual goodwill impairment test to first assess revised qualitative factors to determine whether it is more likely than not that the fair value of a reporting unit is less than its carrying amount. The amendments are effective for annual and interim goodwill impairment tests performed for fiscal years beginning after December 15, 2011.
The Company does not expect that the adoption of the above guidance will have a material impact on the Company's consolidated financial position or results of operations.
NOTE 3. INVENTORY
Inventory consisted of the following as of December 31, 2011 and 2010:
2011 | 2010 | |||||||
Raw Materials | $ | 7,617,243 | $ | 6,100,759 | ||||
Finished Goods | 1,283,093 | 2,233,676 | ||||||
Work in process | 901,551 | 821,897 | ||||||
Parts inventory | 878,564 | 906,876 | ||||||
$ | 10,680,451 | $ | 10,063,208 | |||||
43
LAKE AREA CORN PROCESSORS, LLC
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
DECEMBER 31, 2011, 2010 AND 2009
NOTE 4. INVESTMENTS
RPMG | PGVP (unaudited) | ||||||||||
9/30/2011 | 9/30/2010 | 6/30/2011 | 6/30/2010 | ||||||||
Current assets | 152,212,260 | 125,291,437 | — | — | |||||||
Other assets | 545,238 | 405,396 | 9,600,000 | 8,500,000 | |||||||
Current liabilities | 130,415,610 | 105,780,199 | 8,203 | 6,404 | |||||||
Long-term liabilities | 86,000 | — | — | — | |||||||
Members' equity | 22,255,888 | 19,916,634 | 9,591,797 | 8,493,596 | |||||||
Revenue | 3,066,159,932 | 1,790,452,547 | — | — | |||||||
Net income (loss) | 1,473,661 | 2,737,451 | (909 | ) | (895 | ) | |||||
NOTE 5. SHORT-TERM NOTE PAYABLE
On June 6, 2011, Dakota Ethanol renewed a revolving promissory note from First National Bank of Omaha (FNBO) in the amount of $10,000,000. The note expires on May 1, 2012 and the amount available is subject to certain restrictive covenants establishing minimum reporting requirements, ratios, working capital, net worth and borrowing base requirements. Interest on the outstanding principal balances will accrue at 350 basis points above the 1 month LIBOR rate and is subject to a floor of 4.0 percent. The rate was 4.0 percent at December 31, 2011. There is a commitment fee of 0.4 percent on the unused portion of the $10,000,000 availability. In addition, the bank draws the checking account balance to a minimum balance on a daily basis. The excess cash pays down or the shortfall is drawn upon the note as needed. The note is collateralized by the ethanol plant, its accounts receivable and inventories. On December 31, 2011, Dakota Ethanol had $0 outstanding and $10,000,000 available to be drawn on the revolving promissory note. On December 31, 2010, Dakota Ethanol had $1,872,000 outstanding and $3,128,000 available to be drawn on the revolving promissory note.
NOTE 6. LONG-TERM NOTES PAYABLE
Dakota Ethanol has a note payable to FNBO (Term Note 5).
As part of the note payable agreement, Dakota Ethanol is subject to certain restrictive covenants establishing minimum reporting requirements, ratios, working capital and net worth requirements. The note is collateralized by the ethanol plant and equipment, its accounts receivable and inventories. We are in compliance with our financial covenants as of December 31, 2011.
On June 6, 2011, Dakota Ethanol restructured Term Note 5. Term Note 5 is a reducing revolving note with an availability of $5,000,000. Interest on the outstanding principal balances will accrue at 350 basis points above the 1 month LIBOR rate and is subject to a floor of 4.0 percent. The rate was 4.0 percent at December 31, 2011. Dakota Ethanol may elect to borrow any principal amount repaid on Term Note 5 up to $5,000,000 subject to the terms of the agreement. Should Dakota Ethanol elect not to utilize this feature, the lender will assess an unused commitment fee of 0.4 percent on the unused portion of the note. Term Note 5 has a reducing feature through which the available amount of the note is reduced by $500,000 on the anniversary of the note. The note matures on May 1, 2014. On December 31, 2011, Dakota Ethanol had $0 outstanding and $5,000,000 available to be drawn on Term Note 5. On December 31, 2010, Dakota Ethanol had $0 outstanding and $5,000,000 available to be drawn on Term Note 5.
Dakota Ethanol issued a note payable related to the purchase of land adjacent to the plant site. The note was issued for $450,000. The note matures on December 1, 2012. The note is payable in annual installments of $112,500 plus interest. Interest on outstanding principal balances will accrue at a fixed rate of 7.0 percent. The note is collateralized by the land.
Dakota Ethanol conducted a private placement offering of subordinated unsecured debt securities which closed on May 30, 2009. We issued $1,439,000 in subordinated debt through this offering. Interest on the outstanding balances will accrue at a fixed rate of 9 percent. The securities matured two years from the date of issuance. Interest was annually on January 30th of each year beginning on January 30, 2010. The outstanding balances were paid off during the second quarter of 2011.
44
LAKE AREA CORN PROCESSORS, LLC
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
DECEMBER 31, 2011, 2010 AND 2009
Dakota Ethanol entered into two loan agreements for alternative financing for our corn oil extraction equipment as we had agreed with FNBO; one loan with Rural Electric Economic Development, Inc (REED) and the other loan with First District Development Company (FDDC).
The note to REED, originally for $1 million, has a fixed interest rate of 4.7%. The note requires monthly installments of $18,734 and matures on May 25, 2014. The note is secured by the oil extraction equipment.
The note to FDDC, originally for $200,000, has a fixed interest rate of 5.5%. The note requires monthly installments of $3,820 and matures on May 22, 2014. The note is secured by the oil extraction equipment.
The balance of the notes payable as of December 31, 2011 and 2010 is as follows:
2011 | 2010 | |||||||
Note payable to FNBO Term Note 5 | $ | — | $ | — | ||||
Note payable - Land | 112,500 | 225,000 | ||||||
Note payable - Subordinated notes | — | 1,439,000 | ||||||
Note payable - REED | 513,210 | 708,881 | ||||||
Note payable - FDDC | 103,519 | 142,497 | ||||||
Note payable - Other | 104,426 | 131,771 | ||||||
833,655 | 2,647,149 | |||||||
Less current portion | (387,489 | ) | (1,813,494 | ) | ||||
$ | 446,166 | $ | 833,655 | |||||
Minimum principal payments for the next four years are as follows:
Years Ending September 30, | Amount | |||
2012 | $ | 387,489 | ||
2013 | 288,631 | |||
2014 | 143,827 | |||
2015 | 13,708 | |||
NOTE 7. EMPLOYEE BENEFIT PLANS
Dakota Ethanol maintains a 401(k) plan for the employees who meet the eligibility requirements set forth in the plan documents. Dakota Ethanol matches a percentage of the employees' contributed earnings. Employer contributions to the plan totaled approximately $88,000, $82,000 and $39,000 for the years ended December 31, 2011, 2010 and 2009, respectively.
NOTE 8. FAIR VALUE MEASUREMENTS
The Company complies with the fair value measurements and disclosures standard which defines fair value, establishes a framework for measuring fair value, and expands disclosure for those assets and liabilities carried on the balance sheet on a fair value basis.
The Company's balance sheet contains derivative financial instruments that are recorded at fair value on a recurring basis. Fair value measurements and disclosures require that assets and liabilities carried at fair value be classified and disclosed according to the process for determining fair value. There are three levels of determining fair value.
Level 1 uses quoted market prices in active markets for identical assets or liabilities.
Level 2 uses observable market based inputs or unobservable inputs that are corroborated by market data.
45
LAKE AREA CORN PROCESSORS, LLC
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
DECEMBER 31, 2011, 2010 AND 2009
Level 3 uses unobservable inputs that are not corroborated by market data.
A description of the valuation methodologies used for instruments measured at fair value, as well as the general classification of such instruments pursuant to the valuation hierarchy, is set forth below.
Derivative financial instruments. Commodity futures and options contracts are reported at fair value utilizing Level 1 inputs. For these contracts, the Company obtains fair value measurements from an independent pricing service. The fair value measurements consider observable data that may include dealer quotes and live trading levels from the CBOT and NYMEX markets. Over-the-counter commodity options contracts are reported at fair value utilizing Level 2 inputs. For these contracts, the Company obtains fair value measurements from an independent pricing service. The fair value measurements consider observable data that may include dealer quotes and live trading levels from the over-the-counter markets. Forward purchase contracts are reported at fair value utilizing Level 2 inputs. For these contracts, the Company obtains fair value measurements from local grain terminal bid values. The fair value measurements consider observable data that may include live trading bids from local elevators and processing plants which are based off the CBOT markets.
The following table summarizes financial assets and financial liabilities measured at fair value on a recurring basis as of December 31, 2011 and 2010, segregated by the level of the valuation inputs within the fair value hierarchy utilized to measure fair value:
Total | Level 1 | Level 2 | Level 3 | |||||||||||||
December 31, 2011 | ||||||||||||||||
Assets: | ||||||||||||||||
Derivative financial instruments, | ||||||||||||||||
futures contracts | $ | 1,012,825 | $ | 1,012,825 | $ | — | $ | — | ||||||||
forward contracts | $ | 38,213 | $ | — | $ | 38,213 | — | |||||||||
Liabilities: | ||||||||||||||||
Derivative financial instruments, | ||||||||||||||||
futures contracts | $ | (983,562 | ) | $ | (983,562 | ) | $ | — | $ | — | ||||||
forward contracts | $ | (1,264,918 | ) | $ | — | $ | (1,264,918 | ) | — | |||||||
December 31, 2010 | ||||||||||||||||
Assets: | ||||||||||||||||
Derivative financial instruments, forward contracts | $ | 73,800 | $ | — | $ | 73,800 | $ | — | ||||||||
Liabilities: | ||||||||||||||||
Derivative financial instruments, futures contracts | $ | (2,527,175 | ) | $ | (2,527,175 | ) | $ | — | $ | — | ||||||
Certain financial assets and financial liabilities are measured at fair value on a nonrecurring basis; that is, the instruments are not measured at fair value on an ongoing basis but are subject to fair value adjustments in certain circumstances (for example, when there is evidence of impairment). Financial assets and financial liabilities measured at fair value on a non-recurring basis were not significant at December 31, 2011 and 2010.
Disclosure requirements for fair value of financial instruments require disclosure of the fair value of financial assets and financial liabilities, including those financial assets and financial liabilities that are not measured and reported at fair value on a recurring basis or nonrecurring basis. The methodologies for estimating the fair value of financial assets and financial liabilities that are
46
LAKE AREA CORN PROCESSORS, LLC
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
DECEMBER 31, 2011, 2010 AND 2009
measured at fair value on a recurring or non recurring basis are discussed above. The methodologies for other financial assets and financial liabilities are discussed below.
The Company believes the carrying amount of cash and cash equivalents, accounts receivable, other receivables, due from broker, outstanding checks in excess of bank balance, accounts payable and short-term debt approximates fair value due to the short maturity of these instruments.
The carrying amount of long-term obligations at December 31, 2011 of $929,066 had an estimated fair value of approximately $930,139 based on estimated interest rates for comparable debt. The carrying amount and fair value were $2,794,942 and $2,797,016 respectively at December 31, 2010.
NOTE 9. COMMITMENTS, CONTINGENCIES AND AGREEMENTS
Dakota Ethanol has entered into contracts and agreements regarding the operation and management of the ethanol plant as follows:
Natural Gas - The agreement provides Dakota Ethanol with a fixed transportation rate for natural gas for a ten-year term through August 2021, and is renewable annually thereafter. The agreement does not require minimum purchases of natural gas during their initial term.
Electricity - The agreement provides Dakota Ethanol with electric service for a term of one year. The contract automatically renews unless prior notice of cancellation is given. The agreement sets rates for energy usage based on market rates and requires a minimum purchase of electricity each month during the term of the agreement.
Expenses related to the agreement for the purchase of electricity and natural gas were approximately $8,215,000, $8,779,000, and $9,585,000, for the years ended December 31, 2011, 2010 and 2009, respectively.
Minimum annual payments during the term of the electricity agreement are as follows:
Years Ending December 31, | Amount | |||
2012 | $ | 440,100 | ||
Ethanol Fuel Marketing Agreement - Dakota Ethanol has an agreement with RPMG (a related party, see note 2), a joint venture of ethanol producers, for the sale, marketing, billing and receipt of payment and other administrative services for all ethanol produced by the plant. The agreement expires on March 31, 2012, and is automatically renewed for successive one-year terms unless terminated 90 days prior to expiration.
Distiller's Grain Marketing Agreement - Dakota Ethanol has an agreement with RPMG (a related party, see note 2), for the marketing of all distiller's dried grains produced by the plant. The agreement expires on July 15, 2012 and is automatically renewed for successive one-year terms unless terminated 180 days prior to expiration.
Corn Oil Marketing Agreement - Dakota Ethanol has an agreement with RPMG (a related party, see note 2), for the marketing of all corn oil produced by the plant. The agreement expires on August 11, 2012 and is automatically renewed for successive one-year terms unless terminated 180 days prior to expiration.
Dakota Ethanol receives an incentive payment from the State of South Dakota to produce ethanol. In accordance with the terms of this arrangement, revenue is recorded based on gallons of ethanol sold. Incentive revenue of $293,066, $669,956 and $641,649, was recorded for the years ended December 31, 2011, 2010 and 2009, respectively. Dakota Ethanol did not receive the annual maximum for the 2011 program year due to budget constraints on the State of South Dakota program and will not likely receive the annual maximum under the 2012 program year.
From time to time in the normal course of business the Company can be subject to litigation based on its operations. There is no current litigation that is considered probable and at this time and currently the Company cannot make a reasonable estimate of loss on any claims.
47
LAKE AREA CORN PROCESSORS, LLC
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
DECEMBER 31, 2011, 2010 AND 2009
NOTE 10. RELATED PARTY TRANSACTIONS
Dakota Ethanol has 7% interest in RPMG, and Dakota Ethanol has entered into an ethanol marketing agreement for the exclusive rights to market, sell and distribute the entire ethanol inventory produced by Dakota Ethanol. The marketing fees are included in net revenues.
Dakota Ethanol has entered into a dried distiller's grains marketing agreement with RPMG for the exclusive rights to market, sell and distribute the entire dried distiller's grains inventory produced by Dakota Ethanol. The marketing fees are included in net revenues.
Dakota Ethanol has entered into a corn oil marketing agreement with RPMG for the exclusive rights to market, sell and distribute the entire corn oil inventory produced by Dakota Ethanol. The marketing fees are included in net revenues.
Sales and marketing fees related to the agreements are as follows:
Years Ended December 31, | ||||||||||||
2011 | 2010 | 2009 | ||||||||||
Sales ethanol | $ | 120,982,586 | $ | 80,384,553 | $ | 76,313,982 | ||||||
Sales distiller's grains and corn oil | 8,981,324 | 7,934,785 | 6,183,806 | |||||||||
Marketing fees ethanol | 193,728 | 212,080 | 197,985 | |||||||||
Marketing fees distillers grains and corn oil | 42,658 | 96,596 | 88,533 | |||||||||
Amounts due included in accounts receivable | $ | 3,142,616 | $ | 3,504,400 | $ | 2,973,282 | ||||||
Additional agreements with related parties are included in Note 9.
NOTE 11. TIF BOND GUARANTEE
During December 2003, Dakota Ethanol entered into an agreement to guarantee a bond issued by Lake County, South Dakota. The bond issue was in conjunction with the refunding of the tax increment financing (TIF) bond issued by Lake County in 2001, of which Dakota Ethanol was the recipient of the proceeds. During 2003, Lake County became aware that the taxes collected based on the incremental tax would not be sufficient to cover the debt service of the 2001 bond issue. Based on the aforementioned deficiency and changes in interest rate during December of 2003, Lake County refunded the 2001 bond issue replacing it with two separate bonds. A tax-exempt bond in the amount of $824,599 and a taxable bond in the amount of $1,323,024 were issued. As a part of the refunding, Dakota Ethanol entered into the agreement to guarantee the taxable bond issue. The taxes levied on Dakota Ethanol's property will first go towards the semiannual debt service of the tax-exempt bonds and any remaining taxes will be used for the debt service of the taxable bonds. Dakota Ethanol guarantees any shortfall in debt service for the taxable bonds. The guarantee expires in December of 2018.
The maximum amount of estimated future payments on the taxable bond debt service is $1,065,518 as of December 31, 2011. The carrying amount of the guarantee liability on Dakota Ethanol's balance sheet is $95,411, which represents the estimated shortfall between the taxable bond amount and the amount of taxes estimated to be collected on Dakota Ethanol's property.
Estimated maturities of the guarantee for the next five years are as follows:
48
LAKE AREA CORN PROCESSORS, LLC
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
DECEMBER 31, 2011, 2010 AND 2009
Years Ending December 31, | Amount | ||
2012 | 52,145 | ||
2013 | 34,540 | ||
2014 | 3,923 | ||
2015 | 4,153 | ||
2016 | 650 | ||
Dakota Ethanol has no recourse from third parties or collateral held by third parties related to the guarantee.
NOTE 12. CAPTIVE INSURANCE
The Company is a stockholder in a captive insurance company (Captive). The Captive re-insures losses related to general liability, property and workers compensation claims. Premiums and surplus are paid by the Company through a charge to income in the period to which the premium relates. The Captive reinsures losses not to exceed a predetermined amount. That predetermined amount is fully funded through a portion of paid premium and surplus each year.
For losses covered by the Company's insurance, the Company is solely responsible for paying its deductible. The Company has a deductible of $100,000 for property damage claims plus the first five days of business interruption loss. The Company has a deductible of $10,000 for employee benefits claims. The Company has no deductible for products and premises liability claims and for workers compensation claims. The Company has a catastrophic loss limit of $90 million for property loss claims, a $1 million per occurrence with a $2 million annual aggregate for product liability claims, a $1 million per occurrence with a $10 million annual aggregate for premises liability claims, a $1 million per occurrence with a $2 million annual aggregate for employee benefit liability claims and a $500,000 per occurrence with a $500,000 annual aggregate for workers compensation claims. The Company also purchases a $15 million per occurrence with a $30 million aggregate umbrella to cover above the previously stated liability and workers compensation claims.
Amounts expensed related to the captive insurance were approximately $225,000, $256,000 and $42,000 for the years ending December 31, 2011, 2010 and 2009, respectively.
49
LAKE AREA CORN PROCESSORS, LLC
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
DECEMBER 31, 2011, 2010 AND 2009
NOTE 13. QUARTERLY FINANCIAL REPORTING (UNAUDITED)
Summary quarterly results are as follows:
First Quarter | Second Quarter | Third Quarter | Fourth Quarter | ||||||||||||
Year ended December 31, 2011 | |||||||||||||||
Total revenues | $ | 35,083,109 | $ | 36,943,458 | $ | 37,436,366 | $ | 37,501,921 | |||||||
Gross profit | 5,238,676 | 5,591,145 | 3,594,801 | 5,913,696 | |||||||||||
Income from operations | 4,422,206 | 4,821,183 | 2,799,628 | 5,048,933 | |||||||||||
Net income | 4,434,494 | 4,872,650 | 3,228,398 | 4,910,004 | |||||||||||
Basic and diluted earnings per unit | 0.15 | 0.16 | 0.11 | 0.17 | |||||||||||
Year ended December 31, 2010 | |||||||||||||||
Total revenues | $ | 22,838,763 | $ | 20,245,683 | $ | 24,502,954 | $ | 28,808,389 | |||||||
Gross profit | 3,356,683 | 1,703,097 | 1,916,291 | 3,129,986 | |||||||||||
Income from operations | 2,596,673 | 995,094 | 1,237,184 | 2,355,047 | |||||||||||
Net income | 2,546,687 | 962,841 | 1,213,113 | 2,321,921 | |||||||||||
Basic and diluted earnings per unit | 0.09 | 0.03 | 0.04 | 0.08 | |||||||||||
Year ended December 31, 2009 | |||||||||||||||
Total revenues | $ | 20,975,004 | $ | 22,487,000 | $ | 20,705,138 | $ | 26,173,500 | |||||||
Gross profit | 38,588 | 1,030,400 | 1,255,086 | 6,357,082 | |||||||||||
Income (loss) from operations | (663,874 | ) | 283,257 | 568,372 | 5,535,592 | ||||||||||
Net income (loss) | (1,250,020 | ) | 182,653 | 375,551 | 5,566,585 | ||||||||||
Basic and diluted earnings (loss) per unit | (0.04 | ) | 0.01 | 0.01 | 0.19 | ||||||||||
The above quarterly financial data is unaudited, but in the opinion of management, all adjustments necessary for the fair presentation of the selected data for these interim periods presented have been included.
50
ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND FINANCIAL DISCLOSURE.
None.
ITEM 9A. CONTROLS AND PROCEDURES.
Disclosure Controls and Procedures
Our management, including our President and Chief Executive Officer (the principal executive officer), Scott Mundt, along with our Chief Financial Officer (the principal financial officer), Robbi Buchholtz, have reviewed and evaluated the effectiveness of our disclosure controls and procedures (as defined in Rule 13a-15(e) and Rule 15d-15(e) under the Securities Exchange Act of 1934, as amended) as of December 31, 2011. Based on 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
Our internal control over financial reporting is designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles. Our internal control over financial reporting includes those policies and procedures that:
(i) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of our assets;
(ii) provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with generally accepted accounting principles, and that our receipts and expenditures are being made only in accordance with authorizations of our management and directors; and
(iii) provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use, or disposition of our assets that could have a material effect on the financial statements.
Management, including our Chief Executive Officer and Chief Financial Officer, does not expect that our internal controls will prevent or detect all errors and all fraud. A control system, no matter how well designed and operated, can provide only reasonable, not absolute, assurance that the objectives of the control system are met. Further, the design of a control system must reflect the fact that there are resource constraints, and the benefits of controls must be considered relative to their costs. Because of the inherent limitations in all control systems, no evaluation of internal controls can provide absolute assurance that all control issues and instances of fraud, if any, have been detected. Also, any evaluation of the effectiveness of controls in future periods 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 Securities Exchange Act of 1934, as amended). Management conducted an evaluation of the effectiveness of our internal control over financial reporting based on the criteria set forth in Internal Control-Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission ("COSO"). Based on this evaluation, management has concluded that our internal control over financial reporting was effective as of December 31, 2011.
This annual report does not include an attestation report of our registered public accounting firm regarding internal control over financial reporting. As we are a non-accelerated filer, management's report is not subject to attestation by our registered public accounting firm pursuant to Section 404(c) of the Sarbanes-Oxley Act of 2002 that permits us to provide only management's report in this annual report.
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Changes in Internal Control Over Financial Reporting.
There were no changes in our internal control over financial reporting during the fourth quarter of our fiscal year ended December 31, 2011 which were identified in connection with management's evaluation required by paragraph (d) of rules 13a-15 and 15d-15 under the Exchange Act that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.
ITEM 9B. OTHER INFORMATION.
None.
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 our definitive information 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 (the "2012 Information Statement").
ITEM 10. MANAGERS, EXECUTIVE OFFICERS AND CORPORATE GOVERNANCE
The information required by this Item is incorporated by reference to the 2012 Information Statement.
ITEM 11. EXECUTIVE COMPENSATION.
The information required by this Item is incorporated by reference to the 2012 Information Statement.
ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT AND RELATED MEMBER MATTERS.
The information required by this Item is incorporated by reference to the 2012 Information Statement.
ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS, AND MANAGER INDEPENDENCE.
The information required by this Item is incorporated by reference to the 2012 Information Statement.
ITEM 14. PRINCIPAL ACCOUNTING FEES AND SERVICES.
The information required by this Item is incorporated by reference to the 2012 Information Statement.
PART IV
ITEM 15. EXHIBITS AND FINANCIAL STATEMENT SCHEDULES.
The following exhibits and financial statements are filed as part of, or are incorporated by reference into, this report:
(1) The financial statements appear beginning on page 33 of this report.
(2) All supplemental schedules are omitted because of the absence of conditions under which they are required or because the information is shown in the Consolidated Financial Statements or notes thereto.
(3) The exhibits we have filed herewith or incorporated by reference herein are identified in the Exhibit Index set forth below.
The following exhibits are filed as part of this report. Exhibits previously filed are incorporated by reference, as noted.
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Exhibit No. | Exhibit | Filed Herewith | Incorporated by Reference | |||
2.1 | Plan of Reorganization. | Filed as Exhibit 2.1 on the registrant's Form S-4 filed with the Commission on August 2, 2001 and incorporated by reference herein. | ||||
3.1 | Articles of organization of the registrant. | Filed as Exhibit 3.1 on the registrant's Form S-4 filed with the Commission on August 2, 2001 and incorporated by reference herein. | ||||
3.2 | Amended and restated operating agreement of the registrant. | Filed as Exhibit 3.6 on the registrant's Form 10-K filed with the Commission on March 31, 2005 and incorporated by reference herein. | ||||
3.3 | First amendment to the amended and restated operating agreement of the registrant. | Filed as Exhibit 99.1 on the registrant's Form 8-K filed with the Commission on March 19, 2007 and incorporated by reference herein. | ||||
10.1 | Distillers Grains Marketing Agreement dated July 15, 2008 between RPMG, Inc. and Dakota Ethanol, L.L.C. + | Filed as Exhibit 10.1 on the registrant's Form 10-Q filed with the Commission on August 14, 2008 and incorporated by reference herein. | ||||
10.2 | Contribution Agreement between Renewable Products Marketing Group, LLC and Dakota Ethanol, L.L.C. dated April 1, 2007. | Filed as Exhibit 10.1 on the registrant's Form 10-Q filed with the Commission on August 14, 2007 and incorporated by reference herein. | ||||
10.3 | Addendum to Water Purchase Agreement dated February 28, 2007 between Big Sioux Community Water Systems, Inc. and Dakota Ethanol, L.L.C. | Filed as Exhibit 10.1 on the registrant's Form 10-K filed with the Commission on March 30, 2007. | ||||
10.4 | Risk Management Agreement dated November 28, 2005 between FCStone, LLC and Dakota Ethanol, L.L.C. | Filed as Exhibit 10.1 on the registrant's Form 8-K filed with the Commission on December 2, 2005 and incorporated by reference herein. | ||||
10.5 | Employment Agreement between Scott Mundt and Dakota Ethanol, L.L.C. dated April 1, 2009 | Filed as Exhibit 10.1 on the registrant's Form 10-Q filed with the Commission on May 15, 2009 and incorporated by reference herein. | ||||
10.6 | First Amended and Restated Construction Loan Agreement dated June 18, 2009 between First National Bank of Omaha and Dakota Ethanol, L.L.C. | Filed as Exhibit 10.1 on the registrant's Form 10-Q filed with the Commission on August 12, 2009 and incorporated by reference herein. | ||||
10.7 | Corn Oil Marketing Agreement dated August 11, 2009 between RPMG, Inc. and Dakota Ethanol, L.L.C. + | Filed as Exhibit 10.2 on the registrant's Form 10-Q filed with the Commission on August 12, 2009 and incorporated by reference herein. | ||||
10.8 | First Amendment to First Amended and Restated Construction Loan Agreement between Dakota Ethanol, L.L.C. and First National Bank of Omaha dated May 13, 2010. | Filed as Exhibit 10.1 on the registrant's Form 10-Q filed with the Commission on August 13, 2010 and incorporated by reference herein. | ||||
10.9 | Long Term Reducing Revolving Promissory Note between Dakota Ethanol, L.L.C. and First National Bank of Omaha dated May 13, 2010. | Filed as Exhibit 10.2 on the registrant's Form 10-Q filed with the Commission on August 13, 2010 and incorporated by reference herein. | ||||
10.10 | Operating Line of Credit Promissory Note between Dakota Ethanol, L.L.C. and First National Bank of Omaha dated May 13, 2010. | Filed as Exhibit 10.3 on the registrant's Form 10-Q filed with the Commission on August 13, 2010 and incorporated by reference herein. | ||||
10.11 | Member Ethanol Fuel Marketing Agreement between Dakota Ethanol, LLC and RPMG, Inc. dated March 26, 2010. + | Filed as Exhibit 10.22 on the registrant's Form 10-K filed with the Commission on March 30, 2011 and incorporated by reference herein. | ||||
10.12 | Second Amendment of First Amended and Restated Construction Loan Agreement dated May 12, 2011 between Dakota Ethanol, L.L.C. and First National Bank of Omaha. | Filed as Exhibit 10.1 on the registrant's Form 10-Q filed with the Commission on August 11, 2011 and incorporated by reference herein. | ||||
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10.13 | Operating Line of Credit First Amended and Restated Revolving Promissory Note dated May 12, 2011 between Dakota Ethanol, L.L.C. and First National Bank of Omaha. | Filed as Exhibit 10.2 on the registrant's Form 10-Q filed with the Commission on August 11, 2011 and incorporated by reference herein. | ||||
10.14 | Long Term Reducing Revolver First Amended and Restated Promissory Note dated May 12, 2011 between Dakota Ethanol, L.L.C. and First National Bank of Omaha. | Filed as Exhibit 10.3 on the registrant's Form 10-Q filed with the Commission on August 11, 2011 and incorporated by reference herein. | ||||
31.1 | Certificate Pursuant to 17 CFR 240.13a-14(a) | X | Filed herewith | |||
31.2 | Certificate Pursuant to 17 CFR 240.13a-14(a) | X | Filed herewith | |||
32.1 | Certificate Pursuant to 18 U.S.C. Section 1350 | X | Filed herewith | |||
32.2 | Certificate Pursuant to 18 U.S.C. Section 1350 | X | Filed herewith | |||
101 | The following financial information from Lake Area Corn Processors, LLC's Annual Report on Form 10-K for the fiscal year ended December 31, 2011, formatted in XBRL (eXtensible Business Reporting Language): (i) Consolidated Balance Sheets as of December 31, 2011 and December 31, 2010, (ii) Consolidated Statements of Income for the fiscal years ended December 31, 2011, 2010 and 2009, (iii) Consolidated Statements of Cash Flows for the fiscal years ended December 31, 2011, 2010 and 2009, and (iv) the Notes to Consolidated Financial Statements.** | |||||
+ Confidential Treatment Requested
** Furnished herewith.
SIGNATURES
Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.
LAKE AREA CORN PROCESSORS, LLC | |||
Date: | March 23, 2012 | /s/ Scott Mundt | |
Scott Mundt | |||
President and Chief Executive Officer (Principal Executive Officer) | |||
Date: | March 23, 2012 | /s/ Robbi Buchholtz | |
Robbi Buchholtz | |||
Chief Financial Officer (Principal Financial and Accounting Officer) | |||
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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: | March 23, 2012 | /s/ Ronald Alverson | |
Ronald Alverson, Manager | |||
Date: | March 23, 2012 | /s/ Todd Brown | |
Todd Brown, Manager | |||
Date: | March 23, 2012 | /s/ Randy Hansen | |
Randy Hansen, Manager | |||
Date: | March 23, 2012 | /s/ Rick Kasperson | |
Rick Kasperson, Manager | |||
Date: | March 23, 2012 | /s/ Dale Thompson | |
Dale Thompson, Manager | |||
Date: | March 23, 2012 | /s/ Brian Woldt | |
Brian Woldt, Manager | |||
Date: | March 23, 2012 | /s/ Dave Wolles | |
Dave Wolles, Manager | |||
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